Piedmont Natural Gas (PNY) 10-K 23 Dec 13 2013 FY Annual report Financial data

Document_And_Entity_Informatio

Document And Entity Information (USD $)	12 Months Ended
	Oct. 31, 2013	Dec. 13, 2013	Apr. 30, 2013
Document And Entity Information [Abstract]	'	'	'
Entity Registrant Name	'PIEDMONT NATURAL GAS CO INC	'	'
Entity Central Index Key	'0000078460	'	'
Document Type	'10-K	'	'
Document Period End Date	31-Oct-13	'	'
Document Fiscal Period Focus	'FY	'	'
Document Fiscal Year Focus	'2013	'	'
Amendment Flag	'false	'	'
Entity Current Reporting Status	'Yes	'	'
Entity Voluntary Filers	'No	'	'
Current Fiscal Year End Date	'--10-31	'	'
Entity Filer Category	'Large Accelerated Filer	'	'
Entity Well Known Seasoned Issuer	'Yes	'	'
Entity Common Stock Shares Outstanding	'	76,116,503	'
Entity Public Float	'	'	$2,575,772,202

Consolidated_Balance_Sheets

Consolidated Balance Sheets (USD $)	Oct. 31, 2013	Oct. 31, 2012
Utility Plant	'	'
Utility plant in service	$4,421,937,000	$3,746,178,000
Less accumulated depreciation	1,088,331,000	1,036,814,000
Utility plant in service, net	3,333,606,000	2,709,364,000
Construction work in progress	297,717,000	388,979,000
Plant held for future use	3,155,000	6,743,000
Total utility plant, net	3,634,478,000	3,105,086,000
Other physical property at cost, net	382,000	415,000
Current Assets	'	'
Cash and cash equivalents	8,063,000	1,959,000
Trade accounts receivable, net	79,210,000	56,700,000
Income taxes receivable	31,065,000	31,606,000
Other receivables	1,988,000	2,104,000
Unbilled utility revenues	24,967,000	24,012,000
Gas in storage	73,929,000	72,661,000
Materials, supplies and merchandise	1,725,000	934,000
Gas purchase derivative assets, at fair value	1,834,000	3,153,000
Regulatory assets - current	77,204,000	81,626,000
Prepayments	35,038,000	30,600,000
Deferred income taxes	12,695,000	0
Other current assets	338,000	287,000
Total current assets	348,056,000	305,642,000
Noncurrent Assets	'	'
Equity method investments in non-utility activities	128,469,000	87,867,000
Goodwill	48,852,000	48,852,000
Regulatory assets - noncurrent	169,102,000	211,478,000
Marketable securities, at fair value	2,995,000	2,131,000
Overfunded postretirement asset	28,258,000	0
Other noncurrent assets	8,017,000	8,468,000
Total noncurrent assets	385,693,000	358,796,000
Total Assets	4,368,609,000	3,769,939,000
Stockholders' equity	'	'
Cumulative preferred stock - no par value	0	0
Common stock - no par value	561,644,000	442,461,000
Retained earnings	627,236,000	584,848,000
Accumulated other comprehensive loss	-284,000	-305,000
Total stockholders' equity	1,188,596,000	1,027,004,000
Long-term debt	1,174,857,000	975,000,000
Total capitalization	2,363,453,000	2,002,004,000
Current Liabilities	'	'
Current maturities of long-term debt	100,000,000	0
Short-term debt	400,000,000	365,000,000
Trade accounts payable	96,281,000	94,269,000
Other accounts payable	43,855,000	47,699,000
Accrued interest	28,205,000	21,450,000
Customers' deposits	19,831,000	21,739,000
Current deferred taxes	0	13,542,000
General taxes accrued	21,454,000	21,504,000
Regulatory liabilities - current	0	28,000
Other current liabilities	7,024,000	7,320,000
Total current liabilities	716,650,000	592,551,000
Noncurrent Liabilities	'	'
Deferred income taxes	681,369,000	597,211,000
Unamortized federal investment tax credits	1,402,000	1,669,000
Accumulated provision for postretirement benefits	12,042,000	37,299,000
Regulatory liabilities - noncurrent	541,897,000	489,664,000
Conditional cost of removal obligations	27,016,000	28,629,000
Other noncurrent liabilities	24,780,000	20,912,000
Total noncurrent liabilities	1,288,506,000	1,175,384,000
Commitments and Contingencies	'	'
Total	$4,368,609,000	$3,769,939,000

Consolidated_Balance_Sheets_Pa

Consolidated Balance Sheets (Parentheticals) (USD $)	Oct. 31, 2013	Oct. 31, 2012
Consolidated Balance Sheets (Unaudited)	'	'
Other Physical Property, accumulated depreciation	$876,000	$843,000
Trade Accounts Receivable, allowance for doubtful accounts	$1,604,000	$1,579,000
Cumulative preferred stock, no par value	$0	$0
Cumulative preferred stock, shares authorized	175,000	175,000
Common stock, no par value	$0	$0
Common stock, shares authorized	200,000,000	200,000,000
Common stock, shares outstanding	76,099,000	72,250,000

Consolidated_Statements_of_Com

Consolidated Statements of Comprehensive Income (USD $)	12 Months Ended
	Oct. 31, 2013	Oct. 31, 2012	Oct. 31, 2011
Consolidated Statements of Comprehensive Income	'	'	'
Operating Revenues	$1,278,229,000	$1,122,780,000	$1,433,905,000
Cost of Gas	656,739,000	547,334,000	860,266,000
Margin	621,490,000	575,446,000	573,639,000
Operating Expenses	'	'	'
Operations and maintenance	253,120,000	242,599,000	225,351,000
Depreciation	112,207,000	103,192,000	102,829,000
General taxes	34,635,000	34,831,000	38,380,000
Utility income taxes	77,334,000	69,101,000	64,068,000
Total operating expenses	477,296,000	449,723,000	430,628,000
Operating Income	144,194,000	125,723,000	143,011,000
Other Income (Expense)	'	'	'
Income from equity method investments	26,056,000	23,904,000	24,027,000
Non-operating income	2,839,000	1,288,000	1,762,000
Non-operating expense	-5,122,000	-1,855,000	-3,022,000
Other income (expense) income taxes	-8,612,000	-9,116,000	-8,218,000
Total other income (expense)	15,161,000	14,221,000	14,549,000
Utility Interest Charges	'	'	'
Interest on long-term debt	54,158,000	41,412,000	46,070,000
Allowance for borrowed funds used during construction	-30,975,000	-25,211,000	-8,619,000
Other interest	1,755,000	3,896,000	6,541,000
Total utility interest charges	24,938,000	20,097,000	43,992,000
Net Income	134,417,000	119,847,000	113,568,000
Other Comprehensive Income (Loss), net of tax	'	'	'
Unrealized loss from hedging activities of equity method investments, net of tax	-109,000	-826,000	-576,000
Reclassification adjustment of realized gain from hedging activities of equity method investments included in net income, net of tax	130,000	973,000	654,000
Total other comprehensive income	21,000	147,000	78,000
Comprehensive Income	$134,438,000	$119,994,000	$113,646,000
Average Shares of Common Stock	'	'	'
Basic	74,884,000	71,977,000	72,056,000
Diluted	75,333,000	72,278,000	72,266,000
Earnings Per Share of Common Stock	'	'	'
Basic	$1.80	$1.67	$1.58
Diluted	$1.78	$1.66	$1.57

Consolidated_Statements_of_Com1

Consolidated Statements of Comprehensive Income (Parentheticals) (USD $)	12 Months Ended
	Oct. 31, 2013	Oct. 31, 2012	Oct. 31, 2011
Consolidated Statements of Comprehensive Income	'	'	'
Unrealized Loss From Hedging Activities Of Equity Method Investments Tax	($69,000)	($530,000)	($371,000)
Reclassification adjustment of realized gain from hedging activities of equity method investments included in net income, tax	$85,000	$621,000	$420,000

Consolidated_Statements_Of_Cas

Consolidated Statements Of Cash Flows (USD $)	12 Months Ended
	Oct. 31, 2013	Oct. 31, 2012	Oct. 31, 2011
Cash Flows from Operating Activities	'	'	'
Net Income	$134,417,000	$119,847,000	$113,568,000
Adjustments to reconcile net income to net cash provided by operating activities	'	'	'
Depreciation and amortization	120,797,000	109,230,000	107,046,000
Allowance for doubtful accounts	25,000	232,000	418,000
Net gain on sale of property	-349,000	0	'
Income from equity method investments	-26,056,000	-23,904,000	-24,027,000
Distributions of earnings from equity method investments	22,139,000	19,590,000	22,685,000
Deferred income taxes, net	57,637,000	99,159,000	76,821,000
Changes in assets and liabilities	'	'	'
Gas purchase derivatives, at fair value	1,319,000	-381,000	47,000
Receivables	-23,327,000	5,403,000	-3,019,000
Inventories	-2,059,000	18,897,000	13,789,000
Settlement of legal asset retirement obligations	-2,389,000	-2,038,000	-1,493,000
Overfunded postretirement asset	-28,258,000	22,879,000	-5,537,000
Other assets	47,967,000	-95,582,000	8,360,000
Accounts payable	2,381,000	4,283,000	-4,085,000
Provision for postretirement benefits	-25,257,000	22,628,000	-134,000
Other liabilities	34,260,000	4,272,000	6,806,000
Net cash provided by operating activities	313,247,000	304,515,000	311,245,000
Cash Flows from Investing Activities	'	'	'
Utility capital expenditures	-599,999,000	-529,576,000	-243,641,000
Allowance for borrowed funds used during construction	-30,975,000	-25,211,000	-8,619,000
Contributions to equity method investments	-41,348,000	-3,566,000	-6,222,000
Distributions of capital from equity method investments	4,700,000	5,372,000	3,029,000
Proceeds from sale of property	1,951,000	1,250,000	1,074,000
Investments in marketable securities	-414,000	-606,000	-486,000
Other	2,609,000	3,044,000	2,292,000
Net cash used in investing activities	-663,476,000	-549,293,000	-252,573,000
Cash Flows from Financing Activities	'	'	'
Borrowings under credit facility	10,000,000	350,000,000	1,723,000,000
Repayments under credit facility	-10,000,000	-681,000,000	-1,634,000,000
Net borrowings - commercial paper	35,000,000	365,000,000	'
Proceeds from issuance of long-term debt, net of discount	299,856,000	300,000,000	200,000,000
Retirement of long-term debt	0	'	-256,922,000
Expenses related to issuance of debt	-3,250,000	-3,908,000	-3,902,000
Proceeds from issuance of common stock, net of expenses	92,271,000	'	'
Issuance of common stock through dividend reinvestment and employee stock plans	24,610,000	22,123,000	20,233,000
Repurchases of common stock	0	-26,528,000	-23,004,000
Dividends paid	-92,146,000	-85,693,000	-82,913,000
Other	-8,000	-34,000	-6,000
Net cash provided by (used in) financing activities	356,333,000	239,960,000	-57,514,000
Net Increase (Decrease) in Cash and Cash Equivalents	6,104,000	-4,818,000	1,158,000
Cash and Cash Equivalents at Beginning of Year	1,959,000	6,777,000	5,619,000
Cash and Cash Equivalents at End of Year	8,063,000	1,959,000	6,777,000
Cash Paid During the Year for	'	'	'
Interest	50,275,000	44,571,000	50,136,000
Income Taxes	'	'	'
Income taxes paid	5,760,000	4,770,000	5,649,000
Income taxes refunded	169,000	8,437,000	16,958,000
Income taxes, net	5,591,000	-3,667,000	-11,309,000
Noncash Investing and Financing Activities	'	'	'
Accrued construction expenditures	$39,389,000	$43,643,000	$18,055,000

Consolidated_Statements_Of_Sto

Consolidated Statements Of Stockholders' Equity (USD $)	Total	Common Stock [Member]	Retained Earnings [Member]	Accumulated Other Comprehensive Income (Loss) [Member]
Stockholders' Equity, beginning balance at Oct. 31, 2010	$964,941,000	$445,640,000	$519,831,000	($530,000)
Comprehensive Income	'	'	'	'
Net Income	113,568,000	'	113,568,000	'
Other comprehensive income	78,000	'	'	78,000
Total comprehensive income	113,646,000	'	'	'
Common Stock Issued	24,155,000	24,155,000	'	'
Common Stock Repurchased	-23,004,000	-23,004,000	'	'
Costs of Rescission Offer	-6,000	'	-6,000	'
Tax Benefit from Dividends Paid on ESOP Shares	104,000	'	104,000	'
Dividends Declared	-82,913,000	'	-82,913,000	'
Stockholders' Equity, ending balance at Oct. 31, 2011	996,923,000	446,791,000	550,584,000	-452,000
Comprehensive Income	'	'	'	'
Net Income	119,847,000	'	119,847,000	'
Other comprehensive income	147,000	'	'	147,000
Total comprehensive income	119,994,000	'	'	'
Common Stock Issued	22,198,000	22,198,000	'	'
Common Stock Repurchased	-26,528,000	-26,528,000	'	'
Tax Benefit from Dividends Paid on ESOP Shares	110,000	'	110,000	'
Dividends Declared	-85,693,000	'	-85,693,000	'
Income Loss Hedging Activities Of Equity Method Investments [Abstract]	'	'	'	'
Hedging activities of equity method investments	-305,000	'	'	'
Stockholders' Equity, ending balance at Oct. 31, 2012	1,027,004,000	442,461,000	584,848,000	-305,000
Comprehensive Income	'	'	'	'
Net Income	134,417,000	'	134,417,000	'
Other comprehensive income	21,000	'	'	21,000
Total comprehensive income	134,438,000	'	'	'
Common Stock Issued	119,552,000	119,552,000	'	'
Expenses From Issuance of Common Stock	-369,000	-369,000	'	'
Tax Benefit from Dividends Paid on ESOP Shares	117,000	'	117,000	'
Dividends Declared	-92,146,000	'	-92,146,000	'
Income Loss Hedging Activities Of Equity Method Investments [Abstract]	'	'	'	'
Hedging activities of equity method investments	-284,000	'	'	'
Stockholders' Equity, ending balance at Oct. 31, 2013	$1,188,596,000	$561,644,000	$627,236,000	($284,000)

Recovered_Sheet1

Consolidated Statements of Stockholders Equity (Parentheticals) (USD $)	12 Months Ended
	Oct. 31, 2013	Oct. 31, 2012	Oct. 31, 2011
Consolidated Statements of Stockholders' Equity	'	'	'
Dividends declared per share	$1.23	$1.19	$1.15

Summary_of_Significant_Account

Summary of Significant Accounting Policies	12 Months Ended
	Oct. 31, 2013
Summary Of Significant Accounting Policies Disclosure [Abstract]	'
Significant Accounting Policies Text Block	'
	Notes to Consolidated Financial Statements
	1. Summary of Significant Accounting Policies
	Nature of Operations and Basis of Consolidation
	Piedmont Natural Gas Company, Inc. is an energy services company primarily engaged in the distribution of natural gas to residential, commercial, industrial and power generation customers in portions of North Carolina, South Carolina and Tennessee. We are invested in joint venture, energy-related businesses, including unregulated retail natural gas marketing, regulated interstate natural gas transportation and storage and regulated intrastate natural gas transportation. Our utility operations are regulated by three state regulatory commissions. Unless the context requires otherwise, references to “we,” “us,” “our,” “the Company” or “Piedmont” means consolidated Piedmont Natural Gas Company, Inc. and its subsidiaries. For further information on regulatory matters, see Note 2 to the consolidated financial statements.
	The consolidated financial statements reflect the accounts of Piedmont and its wholly owned subsidiaries whose financial statements are prepared for the same reporting period as Piedmont using consistent accounting policies. Investments in non-utility activities, or joint ventures, are accounted for under the equity method as we do not have controlling voting interests or otherwise exercise control over the management of such companies. Our ownership interest in each entity is recorded in “Equity method investments in non-utility activities” in “Noncurrent Assets” in the Consolidated Balance Sheets at cost plus post-acquisition contributions and earnings based on our share in each of the joint ventures less any distributions received from the joint venture, and if applicable, less any impairment in value of the investment. Earnings or losses from equity method investments are recorded in “Income from equity method investments” in “Other Income (Expense)” in the Consolidated Statements of Comprehensive Income. For further information on equity method investments, see Note 12 to the consolidated financial statements. Revenues and expenses of all other non-utility activities are included in “Non-operating income” in “Other Income (Expense)” in the Consolidated Statements of Comprehensive Income. Inter-company transactions have been eliminated in consolidation where appropriate; however, we have not eliminated inter-company profit on sales to affiliates and costs from affiliates in accordance with accounting regulations prescribed under rate-based regulation.
	We monitor significant events occurring after the balance sheet date and prior to the issuance of the financial statements to determine the impacts, if any, of events on the financial statements to be issued. All subsequent events of which we are aware were evaluated. There are no subsequent events that had a material impact on our financial position, results of operations or cash flows. For further information, see Note 15 to the consolidated financial statements.
	Use of Estimates
	The consolidated financial statements of Piedmont have been prepared in conformity with generally accepted accounting principles in the United States of America (GAAP) and under the rules of the Securities and Exchange Commission (SEC). In accordance with GAAP, we make certain estimates and assumptions regarding reported amounts of assets and liabilities, disclosure of contingent assets and liabilities as of the date of the consolidated financial statements, and reported amounts of revenues and expenses during the periods reported. Actual results could differ significantly from estimates and assumptions.
	Segment Reporting
	Our segments are based on the components of the Company that are evaluated regularly by the chief operating decision maker in deciding how to allocate resources and in assessing performance. Our chief operating decision maker is the executive management team comprised of senior level management. Our segments are identified based on products and services, regulatory environments and our current corporate organization and business decision-making activities. We evaluate the performance of the regulated utility segment based on margin, operations and maintenance (O&M) expenses and operating income. We evaluate the performance of the non-utility activities segment based on earnings from the ventures.
	We have two reportable business segments, regulated utility and non-utility activities. The regulated utility segment is the gas distribution business, where we include the operations of merchandising and its related service work and home warranty programs, with activities conducted by the utility. Operations of our non-utility activities segment are comprised of our equity method investments in joint ventures that are held by our wholly owned subsidiaries. See Note 14 to the consolidated financial statements for further discussion of segments.
	Rate-Regulated Basis of Accounting
	Our utility operations are subject to regulation with respect to rates, service area, accounting and various other matters by the regulatory commissions in the states in which we operate. The accounting regulations provide that rate-regulated public utilities account for and report assets and liabilities consistent with the economic effect of the manner in which independent third-party regulators establish rates. In applying these regulations, we capitalize certain costs and benefits as regulatory assets and liabilities, respectively, in order to provide for recovery from or refund to utility customers in future periods.
	Our regulatory assets are recoverable through either base rates or rate riders specifically authorized by a state regulatory commission. Base rates are designed to provide both a recovery of cost and a return on investment during the period the rates are in effect. As such, all of our regulatory assets are subject to review by the respective state regulatory commissions during any future rate proceedings. In the event that accounting for the effects of regulation were no longer applicable, we would recognize a write-off of the regulatory assets and regulatory liabilities that would result in an adjustment to net income. Our utility operations continue to recover their costs through cost-based rates established by the state regulatory commissions. As a result, we believe that the accounting prescribed under rate-based regulation remains appropriate. It is our opinion that all regulatory assets are recoverable in current rates or in future rate proceedings.
	Regulatory assets and liabilities in the Consolidated Balance Sheets as of October 31, 2013 and 2012 are as follows.
	In thousands	2013			2012
	Regulatory Assets:
	Unamortized debt expense	$	15,423		$	13,583
	Amounts due from customers		66,321			81,626
	Environmental costs		9,416			10,202
	Deferred operations and maintenance expenses		6,376			7,050
	Deferred pipeline integrity expenses		19,449			13,691
	Deferred pension and other retirement benefits costs		20,736			20,139
	Amounts not yet recognized as a component of pension
	and other retirement benefit costs		80,604			123,290
	Regulatory cost of removal asset		22,974			21,129
	Robeson LNG development costs		1,808			-
	Other		3,199			2,394
	Total	$	246,306		$	293,104
	Regulatory Liabilities:
	Regulatory cost of removal obligations	$	493,111		$	464,334
	Amounts due to customers		-			28
	Deferred income taxes		48,647			25,330
	Amounts not yet recognized as a component of pension
	and other retirement costs		139			-
	Total	$	541,897		$	489,692
	As of October 31, 2013, we had regulatory assets totaling $.4 million on which we do not earn a return during the recovery period. The original amortization period for these assets is 15 years and the $.4 million will be fully amortized by 2018. We have $1.9 million related to unrealized mark-to-market amounts on which we do not earn a return until they are recorded in interest-bearing amounts due to/from customer accounts when realized and $80.6 million of regulatory postretirement assets, $23 million of asset retirement obligations (AROs) and $7.9 million of estimated environmental costs on which we do not earn a return. Included in deferred pension and other retirement costs are amounts related to pension funding for our Tennessee jurisdiction. The recovery of these amounts is authorized by the Tennessee Regulatory Authority (TRA) on a deferred cash basis.
	Utility Plant and Depreciation
	Utility plant is stated at original cost, including direct labor and materials, contractor costs, allocable overhead charges, such as engineering, supervision, corporate office salaries and expenses, and pensions and insurance, and an allowance for funds used during construction (AFUDC) that is calculated under a formula prescribed by our state regulators. We apply the group method of accounting, where the costs of homogeneous assets are aggregated and depreciated by applying a rate based on the average expected useful life of the assets. Major expenditures that last longer than a year and improve or lengthen the expected useful life of the overall property from original expectations that are recoverable in regulatory rate base are capitalized while expenditures not meeting these criteria are expensed as incurred. The costs of property retired or otherwise disposed of are removed from utility plant and charged to accumulated depreciation for recovery or refund through future rates. On certain assets, like land, that are nondepreciable, we record a gain or loss upon the disposal of the property that is recorded in “Non-operating income” in “Other Income (Expense)” in the Consolidated Statements of Comprehensive Income.
	The classification of total utility plant, net, for the years ended October 31, 2013 and 2012 is presented below.
	In thousands		2013			2012
	Intangible plant		$	3,374		$	3,374
	Other storage plant			171,349			118,277
	Transmission plant			1,403,829			866,000
	Distribution plant			2,505,160			2,422,988
	General plant			335,847			329,867
	Asset retirement cost			7,565			10,819
	Contributions in aid of construction			-5,187			-5,147
	Total utility plant in service			4,421,937			3,746,178
	Less accumulated depreciation			-1,088,331			-1,036,814
	Total utility plant in service, net			3,333,606			2,709,364
	Construction work in progress			297,717			388,979
	Plant held for future use			3,155			6,743
	Total utility plant, net		$	3,634,478		$	3,105,086
	Contributions in aid of construction represent nonrefundable donations or contributions received from third-parties for partial or full reimbursement for construction expenditures for utility plant in service.
	AFUDC represents the estimated costs of funds from both debt and equity sources used to finance the construction of major projects and is capitalized for ratemaking purposes when the completed projects are placed in service. The portion of AFUDC attributable to borrowed funds is shown as a reduction of “Utility Interest Charges” in the Consolidated Statements of Comprehensive Income. Any portion of AFUDC attributable to equity funds would be included in “Other Income (Expense)” in the Consolidated Statements of Comprehensive Income. For the three years ended October 31, 2013, 2012 and 2011, all of our AFUDC was attributable to borrowed funds.
	AFUDC for the years ended October 31, 2013, 2012 and 2011 is presented below.
	In thousands		2013			2012			2011
	AFUDC		$30,975			$25,211			$8,619
	In accordance with utility accounting practice, we classified real estate and development costs associated with a liquefied natural gas (LNG) peak storage facility in the eastern part of North Carolina as “Plant held for future use” in the Consolidated Balance Sheets, due to construction being suspended in March 2009. As of 2012, approximately $3.2 million of the “Plant held for future use” related to land costs and approximately $3.5 million related to non-real estate costs. In May 2013, we filed a general rate application with the North Carolina Utilities Commission (NCUC) requesting rate recovery of the non-real estate costs. Under the settlement of the 2013 North Carolina general rate proceeding approved by the NCUC in December 2013, we agreed to the amortization and collection of $1.2 million of non-real estate costs to be amortized over 38 months beginning January 1, 2014. We recorded $1.2 million as a regulatory asset along with $.5 million of costs that we allocated to South Carolina operations. We recorded cumulative amortization of $1.8 million of non-real estate costs in fiscal year 2013 that is included in the Consolidated Statements of Comprehensive Income in “Other Income (Expense)” in “Non-operating expense.” For further information on the 2013 general rate proceeding settlement of these costs, see Note 2 to the consolidated financial statements.
	We compute depreciation expense using the straight-line method over periods ranging from 4 to 88 years. The composite weighted-average depreciation rates were 2.77% for 2013, 2.94% for 2012 and 3.19% for 2011.
	Depreciation rates for utility plant are approved by our regulatory commissions. In North Carolina, we are required to conduct a depreciation study every five years and file the results with the regulatory commission. No such five-year requirement exists in South Carolina or Tennessee; however, we periodically propose revised rates in those states based on depreciation studies. Our last system-wide depreciation study based on fiscal year 2009 data was completed in 2011 and filed with the appropriate regulatory commission in all jurisdictions. New depreciation rates were approved effective November 1, 2011 for South Carolina and March 1, 2012 for Tennessee. The new depreciation rates become effective January 1, 2014 in North Carolina under the settlement of the 2013 general rate proceeding.
	As authorized by our regulatory commissions, the estimated costs of removal on certain regulated properties are collected through depreciation expense through rates with a corresponding credit to accumulated depreciation. Our approved depreciation rates are comprised of two components, one based on average service life and one based on cost of removal for certain regulated properties. Therefore, through depreciation expense, we collect and record estimated non-legal costs of removal on any depreciable asset that includes cost of removal in its depreciation rate. Because the estimated removal costs are a non-legal obligation, we account for them as a regulatory liability and present the accumulated removal costs in “Regulatory Liabilities” in “Rate-Regulated Basis of Accounting” in this Note 1. For further discussion of this regulatory liability, see “Asset Retirement Obligations” in this Note 1.
Cash and Cash Equivalents
We consider instruments purchased with an original maturity at date of purchase of three months or less to be cash equivalents, particularly affecting the Consolidated Statements of Cash Flows. We have no restrictions on our cash balances that would impact the payment of dividends as of October 31, 2013 and 2012.
Trade Accounts Receivable and Allowance for Doubtful Accounts
Trade accounts receivable consist of natural gas sales and transportation services, merchandise sales and service work. We bill customers monthly with payment due within 30 days. We maintain an allowance for doubtful accounts, which we adjust periodically, based on the aging of receivables and our historical and projected charge-off activity. Our estimate of recoverability could differ from actual experience based on customer credit issues, the level of natural gas prices and general economic conditions. We write off our customers' accounts when they are deemed to be uncollectible. Pursuant to orders issued by the NCUC, the Public Service Commission of South Carolina (PSCSC) and the TRA, we are authorized to recover all uncollected gas costs through the purchased gas adjustment (PGA). As a result, only the portion of accounts written off relating to the non-gas costs, or margin, is included in base rates and, accordingly, only this portion is included in the provision for uncollectibles expense. Non-regulated merchandise and service work receivables due beyond one year are included in “Other noncurrent assets” in “Noncurrent Assets” in the Consolidated Balance Sheets.
We are exposed to credit risk when we enter into contracts with third parties to buy and sell natural gas. We also enter into short-term contracts with third parties to manage some of our supply and capacity assets for the purpose of maximizing their value. Our policy requires counterparties to have an investment-grade credit rating at the time of the contract. In situations where counterparties do not have investment grade or functionally equivalent credit ratings, our policy requires credit enhancements that include letters of credit or parental guaranties. In either circumstance, the policy specifies limits on the contract amount and duration based on the counterparty's credit rating and/or credit support. In order to minimize our exposure, we continually re-evaluate third-party credit worthiness and market conditions and modify our requirements accordingly.
Our principal business activity is the distribution of natural gas. We believe that we have provided an adequate allowance for any receivables which may not be ultimately collected. As of October 31, 2013 and 2012, our trade accounts receivable consisted of the following.
In thousands			2013			2012
Gas receivables		$	78,540		$	55,956
Non-regulated merchandise and service work receivables			2,274			2,323
Allowance for doubtful accounts			-1,604			-1,579
Trade accounts receivable		$	79,210		$	56,700
A reconciliation of the changes in the allowance for doubtful accounts for the years ended October 31, 2013, 2012 and 2011 is presented below.
In thousands					2013			2012		2011
Balance at beginning of year				$	1,579		$	1,347	$	929
Additions charged to uncollectibles expense					5,314			4,584		4,842
Accounts written off, net of recoveries					-5,289			-4,352		-4,424
Balance at end of year				$	1,604		$	1,579	$	1,347
Inventories
We maintain gas inventories on the basis of average cost. Injections into storage are priced at the purchase cost at the time of injection, and withdrawals from storage are priced at the weighted average purchase price in storage. The cost of gas in storage is recoverable under rate schedules approved by state regulatory commissions. Inventory activity is subject to regulatory review on an annual basis in gas cost recovery proceedings.
We enter into service contracts, or asset management arrangements (AMAs), with counterparties to efficiently manage portions of our gas supply, transportation capacity and storage capacity to serve our customers. These AMAs are structured in compliance with Federal Energy Regulatory Commission (FERC) Order 712. Generally, under an AMA, we receive a fixed monthly payment which is set at inception of the arrangement, and in return, we assign the gas supply, transportation capacity, storage capacity and/or storage inventory to the asset manager for the term of the agreement. The inventory is assigned at no cost, and the same quantities are required to be returned at the expiration of the agreements. One agreement allows us to call on inventory during the summer months to satisfy operational requirements, if needed. The inventory that is assigned to the asset manager is available for use by our customers during the winter heating season, November through March. We account for these amounts on the Consolidated Balance Sheets as a current asset in the inventories section as “Gas in storage.” From the period of April through October, the inventory that is not available for use by our customers is reclassified on the Consolidated Balance Sheets as a current asset in “Prepayments,” and the inventory that is available for use by our customers remains in “Gas in storage.”
At October 31, 2013 and 2012, such counterparties held natural gas storage assets as recorded in “Prepayments,” with a value of $31.5 million and $26.7 million, respectively, through such asset management relationships. Under the terms of the agreements, we receive asset management fees, which are recorded as secondary market transactions and shared between our utility customers and our shareholders. The AMAs expire at various times through March 31, 2014. For further information on the revenue sharing of secondary market transactions, see Note 2 to the consolidated financial statements.
Materials, supplies and merchandise inventories are valued at the lower of average cost or market and removed from such inventory at average cost.
Fair Value Measurements
The carrying values of cash and cash equivalents, receivables, short-term debt, accounts payable, accrued interest and other current liabilities approximate fair value as all amounts reported are to be collected or paid within one year. Our financial assets and liabilities are recorded at fair value. They consist primarily of derivatives that are recorded in the Consolidated Balance Sheets in accordance with derivative accounting standards and marketable securities that are held in rabbi trusts established for our deferred compensation plans and are classified as trading securities. Our qualified pension and postretirement plan assets and liabilities are recorded at fair value in the Consolidated Balance Sheets in accordance with employers' accounting and related disclosures of postretirement plans.
Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date, or exit date. We utilize market data or assumptions that market participants would use in valuing the asset or liability, including assumptions about risk and the risks inherent in the inputs to the valuation technique. These inputs can be readily observable, market corroborated or generally unobservable. We primarily apply the market approach for fair value measurements and endeavor to utilize the best available information. Accordingly, we use valuation techniques that maximize the use of observable inputs and minimize the use of unobservable inputs. The fair value of our financial assets and liabilities are subject to potentially significant volatility based on changes in market prices, the portfolio valuation of our contracts, as well as the maturity and settlement of those contracts, and subsequent newly originated transactions, each of which directly affects the estimated fair value of our financial instruments. We are able to classify fair value balances based on the observance of those inputs at the lowest level that is significant to the fair value measurement, in its entirety, in the following fair value hierarchy levels as set forth in the fair value guidance.
Level 1 inputs are quoted prices (unadjusted) in active markets for identical assets or liabilities as of the reporting date. Active markets have sufficient frequency and volume to provide pricing information for the asset or liability on an ongoing basis. Our Level 1 items consist of financial instruments of exchange-traded derivatives, investments in marketable securities and benefit plan assets held in registered investment companies and individual stocks.
Level 2 inputs are inputs other than quoted prices in active markets included in Level 1 and are either directly or indirectly corroborated or observable as of the reporting date, generally using valuation methodologies. These methodologies are primarily industry-standard methodologies that consider various assumptions, including quoted forward prices for commodities, time value, volatility factors, and current market and contractual prices for the underlying instruments, as well as other relevant economic measures. Substantially all of these assumptions are observable in the marketplace throughout the full term of the instrument, can be derived from observable data or are supported by observable levels at which transactions are executed in the marketplace. We obtain market price data from multiple sources in order to value some of our Level 2 transactions and this data is representative of transactions that occurred in the marketplace. Our Level 2 items include non-exchange-traded derivative instruments, such as some qualified pension plan assets held in hedge fund of funds, commodities fund of funds, common trust funds, collateralized mortgage obligations, swaps, futures, currency forwards, corporate bonds and government and agency obligations that are valued at the closing price reported in the active market for similar assets in which the individual securities are traded or based on yields currently available on comparable securities of issuers with similar credit ratings or based on the most recent available financial information for the respective funds and securities. For some qualified pension plan assets, the determination of Level 2 assets was completed through a process of reviewing each individual security while consulting research and other metrics provided by investment managers, including a pricing matrix detailing the pricing source and security type, annual audited financial statements and a review of valuation policies and procedures used by the investment managers as well as our investment advisor.
Level 3 inputs include significant pricing inputs that are generally less observable from objective sources and may be used with internally developed methodologies that result in management's best estimate of fair value. Our Level 3 inputs include cost estimates for removal (contract fees or manpower/equipment estimates), inflation factors, risk premiums, the remaining life of long-lived assets, the credit adjusted risk free rate to discount for the time value of money over an appropriate time span, and the most recent available financial information of an investment in a diversified private equity fund of funds for some of our qualified pension plan assets. We do not have any other assets or liabilities classified as Level 3.
In determining whether to categorize the fair value measurement of an instrument as Level 2 or Level 3, we must use judgment to assess whether we have the ability as of the measurement date to redeem an investment at its net asset value per share (NAV) in the near term. We consider when we might have the ability to redeem the investment by reviewing contractual restrictions in effect as of the investment date as well as any potential restrictions that the investee may impose. Regarding our benefit plans' investments, “near term” is the ability to redeem an investment in no more than 180 days.
Transfers between different levels of the fair value hierarchy may occur based on the level of observable inputs used to value the instruments for the period. These transfers represent existing assets or liabilities previously categorized as a Level 1 or Level 2 for which the inputs to the estimate became less observable or assets and liabilities previously classified as Level 2 or Level 3 for which the lowest significant input became more observable during the period. Transfers into and out of each level are measured at the actual date of the event or change in circumstances causing the transfer.
For the fair value measurements of our derivatives and marketable securities, see Note 7 to the consolidated financial statements. For the fair value measurements of our benefit plan assets, see Note 9 to the consolidated financial statements.
Goodwill, Equity Method Investments and Long-Lived Assets
Goodwill is the excess of the purchase price over the fair value of identifiable net assets acquired in a business combination. We annually evaluate goodwill for impairment as of October 31, or more frequently if impairment indicators arise during the year. These indicators include, but are not limited to, a significant change in operating performance, the business climate, legal or regulatory factors, or a planned sale or disposition of a significant portion of the business. We test goodwill using a fair value approach at a reporting unit level, generally equivalent to our operating segments as discussed in Note 14 to the consolidated financial statements. An impairment charge would be recognized if the carrying value of the reporting unit, including goodwill, exceeded its fair value. All of our goodwill is attributable to the regulated utility segment.
Our annual goodwill impairment assessment was performed as of October 31, 2013, and we determined that there was no impairment to the carrying value of our goodwill. No impairment has been recognized during the years ended October 31, 2013, 2012 and 2011. The fair value of our regulated utility reporting unit substantially exceeds the carrying value, including goodwill.
We review our equity method investments and long-lived assets for impairment whenever events or changes in circumstances indicate that the carrying amounts may not be recoverable. There were no events or circumstances during the years ended October 31, 2013, 2012 and 2011 that resulted in any impairment charges. For further information on equity method investments, see Note 12 to the consolidated financial statements.
Marketable Securities
We have marketable securities that are invested in money market and mutual funds that are liquid and actively traded on the exchanges. These securities are assets that are held in rabbi trusts established for our deferred compensation plans. For further information on the deferred compensation plans, see Note 9 to the consolidated financial statements.
We have classified these marketable securities as trading securities since their inception as the assets are held in rabbi trusts. Trading securities are recorded at fair value on the Consolidated Balance Sheets with any gains or losses recognized currently in earnings. We do not intend to engage in active trading of the securities, and participants in the deferred compensation plans may redirect their investments at any time. We have matched the current portion of the deferred compensation liability with the current asset and noncurrent deferred compensation liability with the noncurrent asset; the current portion has been included in “Other current assets” in “Current Assets” in the Consolidated Balance Sheets.
The money market investments in the trusts approximate fair value due to the short period of time to maturity. The fair values of the equity securities are based on quoted market prices as traded on the exchanges. The composition of these securities as of October 31, 2013 and 2012 is as follows.
In thousands	2013						2012
	Cost			Fair Value			Cost		Fair Value
Current trading securities:
Money markets	$	-		$	-		$	-	$	-
Mutual funds		134			199			134		157
Total current trading securities		134			199			134		157
Noncurrent trading securities:
Money markets		380			380			243		243
Mutual funds		1,995			2,615			1,668		1,888
Total noncurrent trading securities		2,375			2,995			1,911		2,131
Total trading securities	$	2,509		$	3,194		$	2,045	$	2,288
Unamortized Debt Expense
Unamortized debt expense consists of costs, such as underwriting and broker dealer fees, discounts and commissions, legal fees, accountant fees, registration fees and rating agency fees, related to issuing long-term debt and the short-term syndicated revolving credit facility. We amortize long-term debt expense on a straight-line basis, which approximates the effective interest method, over the life of the related debt which has lives ranging from 5 to 30 years. We amortize bank debt expense over the life of the syndicated revolving credit facility, which is five years.
Should we reacquire long-term debt prior to its term date and simultaneously issue new debt, we defer the gain or loss resulting from the transaction, essentially the remaining unamortized debt expense, and amortize it over the life of the new debt in accordance with established regulatory practice. Where the refunding of the debt is not simultaneous, we defer the gain or loss resulting from the reacquisition of the debt and amortize it over the remaining life of the redeemed debt in accordance with established regulatory practice. For income tax purposes, any gain or loss would be recognized as incurred.
Issuances and Repurchases of Common Stock
As discussed in Note 6 to the consolidated financial statements, we repurchase shares on the open market and such shares are then cancelled and become authorized but unissued shares. It is our policy to issue new shares for share-based employee awards and shareholder and employee investment plans. We present net shares issued under these awards and plans in “Common Stock Issued” in the Consolidated Statements of Stockholders' Equity. Shares withheld by us to satisfy tax withholding obligations related to the vesting of shares awarded under the Incentive Compensation Plan have been immaterial to date.
Asset Retirement Obligations
The accounting guidance for AROs addresses the financial accounting and reporting for AROs associated with the retirement of long-lived assets that result from the acquisition, construction, development and operation of the assets. The accounting guidance requires the recognition of the fair value of a liability for AROs in the period in which the liability is incurred if a reasonable estimate of fair value can be made. We have determined that conditional AROs exist for our underground mains and services.
We have costs of removal that are non-legal obligations as defined by the accounting guidance. The costs of removal are a component of our depreciation rates in accordance with long-standing regulatory treatment. Because these estimated removal costs meet the requirements of rate-regulated accounting guidance, we have accounted for these non-legal AROs in “Regulatory Liabilities” as presented in “Rate-Regulated Basis of Accounting” in this Note 1. In the rate setting process, the liability for non-legal costs of removal is treated as a reduction to the net rate base upon which the regulated utility has the opportunity to earn its allowed rate of return. For further discussion of these costs of removal as a component of depreciation, see “Utility Plant and Depreciation” in this Note 1.
We apply the accounting guidance for conditional AROs that requires recognition of a liability for the fair value of conditional AROs when incurred if the liability can be reasonably estimated. The NCUC, the PSCSC and the TRA have approved placing these ARO costs in deferred accounts to preserve the regulatory treatment of these costs; therefore, accretion is not reflected in the Consolidated Statements of Comprehensive Income as the regulatory treatment provides for deferral of the accretion as a regulatory asset with a corresponding deferral of the accretion recorded as a regulatory liability. AROs are capitalized concurrently by increasing the carrying amount of the related asset by the same amount as the regulatory liability. In periods subsequent to the initial measurement, any changes in the liability resulting from the passage of time (accretion) or due to the revisions of either timing or the amount of the originally estimated cash flows to settle conditional AROs must be recognized. The estimated cash flows to settle conditional AROs are discounted using the credit adjusted risk-free rate, which ranged from 4.61% to 5.87% with a weighted average of 5.73% for the twelve months ended October 31, 2013. The estimate was calculated using a time value weighted average credit adjusted risk-free rate. We have recorded a liability on our distribution and transmission mains and services.
The cost of removal obligations recorded in the Consolidated Balance Sheets as of October 31, 2013 and 2012 are presented below.
In thousands	2013			2012
Regulatory non-legal AROs	$	493,111		$	464,334
Conditional AROs		27,016			28,629
Total cost of removal obligations	$	520,127		$	492,963
A reconciliation of the changes in conditional AROs for the year ended October 31, 2013 and 2012 is presented below.
In thousands		2013			2012
Beginning of period		$	28,629		$	27,395
Liabilities incurred during the period			2,052			1,705
Liabilities settled during the period			-2,389			-2,038
Accretion			1,641			1,570
Adjustment to estimated cash flows			-2,917			-3
End of period		$	27,016		$	28,629
Revenue Recognition
We record revenues when services are provided to our distribution service customers. Utility sales and transportation revenues are based on rates approved by state regulatory commissions. Base rates charged to jurisdictional customers may not be changed without approval by the regulatory commission in that jurisdiction; however, the wholesale cost of gas component of rates may be adjusted periodically under PGA provisions. In North Carolina, a margin decoupling mechanism provides for the recovery of our approved margin from residential and commercial customers on an annual basis independent of consumption patterns. The margin decoupling mechanism provides for semi-annual rate adjustments to refund any over-collection of margin or to recover any under-collection of margin. In South Carolina, a rate stabilization adjustment (RSA) tariff mechanism achieves the objectives of margin decoupling for residential and commercial customers with a one year lag. Under the RSA tariff mechanism, we reset our rates in South Carolina based on updated costs and revenues on an annual basis. In South Carolina and Tennessee, a weather normalization adjustment (WNA) is calculated for residential and commercial customers during the winter heating season November through March. Effective March 1, 2012, the WNA mechanism in Tennessee was expanded to include the additional months of April and October in the winter heating season. The WNA mechanisms are designed to partially offset the impact that warmer-than-normal or colder-than-normal weather has on customer billings during the winter heating season. The WNA formulas do not ensure full recovery of approved margin during periods when customer consumption patterns vary from those used to establish the WNA factors. In all states, the gas cost portion of our costs is recoverable through PGA procedures and is not affected by the margin decoupling mechanism or the WNA mechanisms.
Revenues are recognized monthly on the accrual basis, which includes estimated amounts for gas delivered to customers but not yet billed under the cycle-billing method from the last meter reading date to month end. The unbilled revenue estimate reflects factors requiring judgment related to estimated usage by customer class, customer mix, changes in weather during the period and the impact of the WNA or margin decoupling mechanisms, as applicable.
Secondary market revenues associated with the commodity are recognized when the physical sales are delivered based on contract or market prices. Asset management fees for storage and transportation remitted on a monthly basis are recognized as earned given the monthly capacity costs associated with the contracts involved. Asset management fees remitted in a lump sum are deferred and amortized ratably into income over the period in which they are earned, which is typically the contract term. See Note 2 to the consolidated financial statements regarding revenue sharing of secondary market transactions.
Utility sales, transportation and secondary market revenues are reported net of excise taxes, sales taxes and franchise fees. For further information regarding taxes, see “Taxes” in this Note 1.
Non-regulated merchandise and service work includes the sale, installation and/or maintenance of natural gas appliances and gas piping beyond the meter. Revenue is recognized when the sale is made or the work is performed. If the customer is eligible for and elects financing through us, the finance fee income is recognized on a monthly basis based on principal, rate and term.
Cost of Gas and Deferred Purchased Gas Adjustments
We charge our utility customers for natural gas consumed using natural gas cost recovery mechanisms as set by the regulatory commissions in states in which we operate. Rate schedules for utility sales and transportation customers include PGA provisions that provide for the recovery of prudently incurred gas costs. With regulatory commission approval, we revise rates periodically without formal rate proceedings to reflect changes in the wholesale cost of gas. We charge our secondary market customers for natural gas based on negotiated contract terms. Under PGA provisions, charges to cost of gas are based on the amount recoverable under approved rate schedules. Within our cost of gas, we include amounts for lost and unaccounted for gas and adjustments to reflect the gains and losses associated with gas price hedging derivatives. By jurisdiction, differences between gas costs incurred and gas costs billed to customers are deferred and included in “Amounts due from customers” in “Regulatory Assets” or “Amounts due to customers” in “Regulatory Liabilities” as presented in “Rate-Regulated Basis of Accounting” in this Note 1. We review gas costs and deferral activity periodically (including deferrals under the margin decoupling and WNA mechanisms) and, with regulatory commission approval, increase rates to collect under-recoveries or decrease rates to refund over-recoveries over a subsequent period.
Taxes
We have two categories of income taxes in the Consolidated Statements of Comprehensive Income: current and deferred. Current income tax expense consists of federal and state income taxes less applicable tax credits related to the current year. Deferred income tax expense generally is equal to the changes in the deferred income tax liability and regulatory tax liability during the year. Deferred taxes are primarily attributable to utility plant, deferred gas costs, revenues and cost of gas, equity method investments, benefit of loss carryforwards and employee benefits and compensation. The determination of our provision for income taxes requires judgment, the use of estimates, and the interpretation and application of complex tax laws. Judgment is required in assessing the timing and amounts of deductible and taxable items.
Deferred income taxes are determined based on the estimated future tax effects of differences between the book and tax basis of assets and liabilities. We have provided valuation allowances to reduce the carrying amount of deferred tax assets to amounts that are more likely than not to be realized. To the extent that the establishment of deferred income taxes is different from the recovery of taxes through the ratemaking process, the differences are deferred in accordance with rate-regulated accounting provisions, and a regulatory asset or liability is recognized for the impact of tax expenses or benefits that will be collected from or refunded to customers in different periods pursuant to rate orders.
Deferred investment tax credits, including energy credits, associated with our utility operations are presented in the Consolidated Balance Sheets. We amortize these deferred investment and energy tax credits to income over the estimated useful lives of the property to which the credits relate.
We recognize accrued interest and penalties, if any, related to uncertain tax positions as operating expenses in the Consolidated Statements of Comprehensive Income. This is consistent with the recognition of these items in prior reporting periods.
Excise taxes, sales taxes and franchises fees separately stated on customer bills are recorded on a net basis as liabilities payable to the applicable jurisdictions. All other taxes other than income taxes are recorded as general taxes. General taxes consist of property taxes, payroll taxes, Tennessee gross receipt taxes, franchise taxes, tax on company use and other miscellaneous taxes.
Consolidated Statements of Cash Flows
With respect to cash overdrafts, book overdrafts are included within operating cash flows while any bank overdrafts are included with financing cash flows.
Recently Issued Accounting Guidance
In December 2011, the Financial Accounting Standards Board (FASB) issued accounting guidance to improve disclosures and make information more comparable to International Financial Reporting Standards regarding the nature of an entity's rights of offset and related arrangements associated with its financial instruments and derivative instruments. The guidance requires an entity to disclose information about offsetting and related arrangements in tabular format to enable users of financial statements to understand the effect of those arrangements on the entity's financial position. The new disclosure requirements are effective for annual periods beginning after January 1, 2013 and interim periods within those periods, and require retrospective application in all periods presented. We will adopt this offsetting disclosure guidance for the first quarter of our fiscal year ending October 31, 2014. The adoption of this disclosure guidance will have no impact on our financial position, results of operations or cash flows.
In November 2012, the FASB finalized the presentation disclosures on items reclassified from accumulated other comprehensive income (OCI). We adopted this disclosure guidance for the second quarter of our fiscal year ending October 31, 2013. The adoption of this guidance did not have a material impact on our financial position, results of operations or cash flows.
In July 2013, the FASB issued accounting guidance on presenting an unrecognized tax benefit when net operating loss (NOL) carryforwards exist. The guidance was issued in an effort to eliminate diversity in practice resulting from a lack of guidance on this topic in current US GAAP. The update provides that an unrecognized tax benefit, or a portion of an unrecognized tax benefit, should be presented in the financial statements as a reduction to a deferred tax asset for a NOL carryforward, a similar tax loss, or a tax credit carryforward, except under certain circumstances outlined in the update. The amendments in the update are effective for annual periods, and interim periods within those periods, beginning after December 15, 2013, with early adoption permitted. The adoption of this disclosure guidance will have no impact on our financial position, results of operations or cash flows.
Reclassifications and Changes in Presentation
Reclassifications have been made to certain prior year financial statements to conform with the current year presentation. We have changed our 2012 presentation of regulatory assets and liabilities on the Consolidated Balance Sheets where regulatory assets and liabilities were presented in various line items to the 2013 presentation of a more cohesive presentation of the regulatory balances in single “Regulatory assets” and “Regulatory liabilities” line items. The corresponding line items within “Cash Flows from Operating Activities” in the Consolidated Statements of Cash Flows were also changed to reflect this balance sheet presentation; the reclassifications had no effect on previously reported amounts for net cash flows from operating, investing or financing activities. The changes in presentation had no effect on total assets or liabilities reported in the Consolidated Balance Sheets, or on any subtotals within the Consolidated Balance Sheets, or on previously reported operating income, net income, comprehensive income, earnings per share (EPS) or stockholders' equity.

Regulatory_Matters

Regulatory Matters	12 Months Ended
	Oct. 31, 2013
Public Utilities Rate Matters [Abstract]	'
Public Utilities Disclosure Text Block	'
	2. Regulatory Matters
	Our utility operations are regulated by the NCUC, PSCSC and TRA as to rates, service area, adequacy of service, safety standards, extensions and abandonment of facilities, accounting and depreciation. We are also regulated by the NCUC as to the issuance of long-term debt and equity securities.
	The NCUC and the PSCSC regulate our gas purchasing practices under a standard of prudence and audit our gas cost accounting practices. The TRA regulates our gas purchasing practices under a gas supply incentive program which compares our actual costs to market pricing benchmarks. As part of this jurisdictional oversight, all three regulatory commissions address our gas supply hedging activities. Additionally, all three regulatory commissions allow for recovery of uncollectible gas costs through the PGA. The portion of uncollectibles related to gas costs is recovered through the deferred account and only the non-gas costs, or margin, portion of uncollectibles is included in base rates and uncollectibles expense.
	North Carolina
	The North Carolina General Assembly enacted the Clean Water and Natural Gas Critical Needs Act of 1998 which provided for the issuance of $200 million of general obligation bonds of the state for the purpose of providing grants, loans or other financing for the cost of constructing natural gas facilities in unserved areas of North Carolina. In 2000, the NCUC issued an order awarding Eastern North Carolina Natural Gas Company (EasternNC) an exclusive franchise to provide natural gas service to 14 counties in the eastern-most part of North Carolina that had not been able to obtain gas service because of the relatively small population of those counties and the resulting economic infeasibility of providing service and granted $38.7 million in state bond funding. In 2001, the NCUC issued an order granting EasternNC an additional $149.6 million, for a total of $188.3 million. With the 2003 acquisition and subsequent merger of EasternNC into our regulated utility segment, we are required to provide an accounting of the operational feasibility of this area to the NCUC every two years. Should this operational area become economically feasible and generate a profit, which we believe is unlikely, we would begin to repay the state bond funding.
	The NCUC had allowed EasternNC to defer its O&M expenses during the first eight years of operation or until the first rate case order, whichever occurred first, with a maximum deferral of $15 million. The deferred amounts accrued interest at a rate of 8.69% per annum. In December 2003, the NCUC confirmed that these deferred expenses should be treated as a regulatory asset for future recovery from customers to the extent they are deemed prudent and proper. As a part of the 2005 general rate case proceeding, deferral ceased on October 31, 2005, and the balance in the deferred account as of June 30, 2005 of $7.9 million, including accrued interest, is being amortized over 15 years beginning November 1, 2005. Under the settlement of the 2008 general rate proceeding, the unamortized balance of the EasternNC deferred O&M expenses was $9 million at October 31, 2008. This balance is accruing interest at a rate of 7.84% per annum and is being amortized over a twelve year period. As of October 31, 2013 and 2012, we had unamortized balances of $6.4 million and $7 million, respectively.
	Under the settlement of the 2013 general rate proceeding discussed below, the unamortized balance of the EasternNC deferred O&M expenses was $6.3 million as of December 31, 2013. This balance will accrue interest at a rate of 6.55% per annum and will be amortized over an 82-month period beginning January 1, 2014.
	We incur certain pipeline integrity management costs in compliance with the Pipeline Safety Improvement Act of 1992 and regulations of the United States Department of Transportation. The NCUC approved deferral treatment of the O&M costs applicable to all incremental external expenditures beginning November 1, 2004. Under the settlement of the 2008 general rate proceeding, the pipeline integrity management costs incurred between July 1, 2005 and June 30, 2008 of $4.6 million were fully amortized over a three-year period beginning November 1, 2008. The approved balance for recovery of actual pipeline integrity management O&M costs incurred between July 1, 2008 through August 31, 2013 as established in the settlement of the 2013 general rate proceeding discussed below was $17.3 million to be amortized over a five-year period beginning January 1, 2014. As of October 31, 2013, we have recorded a regulatory asset for deferred pipeline integrity expenses of $19.4 million. The existing regulatory asset treatment for ongoing pipeline integrity management costs continues until another recovery mechanism is established in a future rate proceeding.
	Based on the approval of the settlement of the 2013 NCUC general rate proceeding discussed below, future capital expenditures that are incurred to comply with federal pipeline safety and integrity requirements will be separately tracked and recovered on an annual basis through an integrity management rider (IMR). The settlement also would approve recovery of $6.3 million of deferred North Carolina environmental costs over a five-year period beginning January 2014.
	In North Carolina, our recovery of gas costs is subject to annual gas cost proceedings to determine the prudence of our gas purchases. Costs have never been disallowed on the basis of prudence.
	In January 2011, the NCUC approved our accounting of gas costs for the twelve months ended May 31, 2010, with adjustments agreed to by us as a result of the North Carolina Public Staff's audit of the 2010 gas cost review period. We were deemed prudent on our gas purchasing policies and practices during this review period and allowed 100% recovery.
	In January 2012, the NCUC approved our accounting of gas costs for the twelve months ended May 31, 2011, with adjustments agreed to by us as a result of the North Carolina Public Staff's audit of the 2011 gas cost review period. We were deemed prudent on our gas purchasing policies and practices during this review period and allowed 100% recovery.
	In November 2012, the NCUC approved our accounting of gas costs for the twelve months ended May 31, 2012. We were deemed prudent on our gas purchasing policies and practices during this review period and allowed 100% recovery.
	In November 2013, the NCUC approved our accounting of gas costs for the twelve months ended May 31, 2013. We were deemed prudent on our gas purchasing policies and practices during this review period and allowed 100% recovery.
	Our gas cost hedging plan for North Carolina is designed to provide a level of protection against significant price increases, targets a percentage range of 22.5% to 45% of annual normalized sales volumes for North Carolina and operates using historical pricing indices that are tied to future projected gas prices as traded on a national exchange. Unlike South Carolina as discussed below, recovery of costs associated with the North Carolina hedging plan is not pre-approved by the NCUC, and the costs are treated as gas costs subject to the annual gas cost prudence review. Any gain or loss recognition under the hedging program is a reduction in or an addition to gas costs, respectively, which, along with any hedging expenses, are flowed through to North Carolina customers in rates. The gas cost review orders issued January 2011, January 2012, November 2012 and November 2013 found our hedging activities during the review periods to be reasonable and prudent.
	In October 2012, we filed a petition with the NCUC seeking authority to transfer the total balance of $6.7 million of capital costs held in “Plant held for future use” in “Utility Plant” in the Consolidated Balance Sheets to a deferred regulatory asset account, effective November 1, 2012. This balance in “Plant held for future use” was comprised of real estate and non-real estate costs and related to the development of a LNG facility in Robeson County, North Carolina, construction of which was suspended by Piedmont in March 2009. In April 2013, we withdrew the petition, citing our intent to address the matter in a general rate application. The appropriate treatment of the Robeson County LNG costs was addressed in the general rate settlement discussed below.
	In May 2013, we filed a general rate application with the NCUC requesting an increase in rates and charges to produce overall increased annual revenues of $79.8 million, or 9.3% above the current annual revenues. In October, we reached a settlement with the NCUC Public Staff and intervening parties, in which the parties agreed to the following:
	Adjusted rates and charges to provide incremental annual total revenues of $30.7 million, including $16.8 million related to gas utility margin and $13.8 million related to increased fixed gas costs, and annual pre-tax income of $24.2 million after taking into account revised depreciation rates and changes to regulatory asset amortizations.
	An overall rate base of $1.8 billion, an equity capital structure component of 50.7% and a return on common equity of 10%.
	A new IMR designed to separately track and recover the costs associated with capital expenditures that are made to comply with federal pipeline safety and integrity requirements outside of a general rate case. IMR filings will occur annually in November to capture costs closed to plant through October with revised rates effective in February, which will provide revised rates in 2014.
	Lower depreciation rates that provide increased annual pre-tax income of $10.9 million. These new lower rates reflect the most recent study conducted in 2009, as discussed in Note 1 to the consolidated financial statements.
	Amortization and collection of $1.2 million of certain non-real estate costs associated with the initial development of the Robeson County LNG facility as discussed above.
	Amortization and collection of certain environmental expenses and pipeline safety and integrity compliance expenses through August 31, 2013 that had been deferred since our last general rate case in 2008.
	Provision for ongoing increased annual contributions to fund pipeline safety and integrity research.
	Future adjustments to rates to recognize the lower state corporate income taxes from North Carolina legislation for fiscal years beginning November 1, 2014 and November 1, 2015.
	With the approval on December 17, 2013 by the NCUC of the settlement discussed above, the new rates will become effective January 1, 2014. The increase in annual total revenues of $30.7 million represents a 3.58% increase in total revenues, or .7% annual increase per year since the last general rate proceeding in 2008.
	South Carolina
	We currently operate under the Natural Gas Rate Stabilization Act of 2005 in South Carolina. If a utility elects to operate under this act, the annual cost and revenue filing will provide that the utility's rate of return on equity will remain within a 50-basis point band above or below the last approved allowed rate of return on equity.
	In June 2011, we filed with the PSCSC a quarterly monitoring report for the twelve months ended March 31, 2011 and a cost and revenue study as permitted by the RSA requesting a change in rates from those approved by the PSCSC in the October 2010 order. In October 2011, the PSCSC issued an order approving a settlement between the Office of Regulatory Staff (ORS) and us that resulted in a $3.1 million annual decrease in margin based on a return on equity of 11.3% and a decrease of $1.9 million in depreciation rates for South Carolina utility plant in service, effective November 1, 2011.
	In June 2012, we filed with the PSCSC a quarterly monitoring report for the twelve months ended March 31, 2012 and a cost and revenue study as permitted by the RSA requesting a change in rates from those approved by the PSCSC in the October 2011 order. In October 2012, the PSCSC issued an order approving a settlement agreement between the ORS and us that resulted in a $1.1 million annual decrease in margin based on a return on equity of 11.3%, effective November 1, 2012.
	In June 2013, we filed with the PSCSC a quarterly monitoring report for the twelve months ended March 31, 2013 and a cost and revenue study as permitted by the RSA requesting a change in rates from those approved by the PSCSC in the October 2012 order. In October 2013, the PSCSC issued an order approving a settlement agreement between the ORS and us that resulted in a $.1 million annual decrease in margin based on a return on equity of 11.3%, effective November 1, 2013. The PSCSC also approved the recovery of $.2 million of our deferred South Carolina environmental costs over a one-year period beginning November 2013.
	In South Carolina, our recovery of gas costs is subject to annual gas cost proceedings to determine the prudence of our gas purchases. Costs have never been disallowed on the basis of prudence.
	The PSCSC has approved a gas cost hedging plan for the purpose of cost stabilization for South Carolina customers. The plan targets a percentage range of 22.5% to 45% of annual normalized sales volumes for South Carolina and operates using historical pricing indices tied to future projected gas prices as traded on a national exchange. All properly accounted for costs incurred in accordance with the plan are deemed to be prudently incurred and recovered in rates as gas costs. Any gain or loss recognized under the hedging program is a reduction in or an addition to gas costs, respectively, and flows through to South Carolina customers in rates.
	In August 2011, the PSCSC approved our PGAs and found our gas purchasing policies to be prudent for the twelve months ended March 31, 2011. The settlement agreement also stipulated that our hedging program should no longer have a required minimum volume of hedging.
	In August 2012, the PSCSC approved our PGAs and found our gas purchasing policies to be prudent for the twelve months ended March 31, 2012.
	In August 2013, the PSCSC approved our PGAs and found our gas purchasing policies to be prudent for the twelve months ended March 31, 2013.
	Tennessee
	In February 2010, we filed a petition with the TRA to adjust the applicable rate for the collection of the Nashville franchise fee from certain customers. The proposed rate adjustment was calculated to recover the net $2.9 million of under-collected Nashville franchise fee payments as of May 31, 2009. In April 2010, the TRA passed a motion approving a new Nashville franchise fee rate designed to recover only the net under-collections that have accrued since June 1, 2005, which would have denied recovery of $1.5 million. In October 2011, the TRA issued an order denying us the recovery of $1.5 million of franchise fees consistent with its April 2010 motion, and we recorded $1.5 million in “Operating Expenses” as “Operations and maintenance” in the Consolidated Statements of Comprehensive Income. In November 2011, we filed for reconsideration, which was granted that month. In February 2012, a hearing on this matter was held before the TRA. In May 2012, the TRA approved the recovery of an additional $.5 million in under-collected Nashville franchise fees covering years 2002 through May 2005, which we recorded as a reduction in O&M expenses. The written order was issued by the TRA in June 2012.
	In Tennessee, the Tennessee Incentive Plan (TIP) replaced annual prudence reviews under the Actual Cost Adjustment (ACA) mechanism in 1996 by benchmarking gas costs against amounts determined by published market indices and by sharing secondary market (capacity release and off-system sales) activity performance. In 2007, the TRA modified our TIP to clarify and simplify the calculation of allocating secondary marketing gains and losses to ratepayers and shareholders by adopting a uniform 75/25 sharing ratio. The TRA also maintained the $1.6 million annual incentive cap for us on gains and losses, improved the transparency of plan operations by an agreed to request for proposal procedures for asset management transactions and provided for a triennial review of TIP operations by an independent consultant.
	In September 2010, we filed an annual report with the TRA reflecting the shared gas cost savings from gains and losses derived from gas purchase benchmarking and secondary market transactions for the twelve months ended June 30, 2010 under the TIP. In May 2011, the TRA issued an order approving our TIP account balances.
	In December 2010, we filed our report with the TRA for the eighteen months ended June 30, 2010 reflecting the transactions in the deferred gas cost account for the ACA mechanism. This one-time eighteen month audit period was designed to synchronize the ACA audit year with the TIP year in order to facilitate the audit process for future periods. In August 2011, the TRA approved the deferred gas cost account balances and issued its written order.
	In August 2011, we filed an annual report with the TRA reflecting the shared gas cost savings from gains and losses derived from gas purchase benchmarking and secondary market transactions for the twelve months ended June 30, 2011 under the TIP. In March 2012, the TRA approved our TIP account balance. The TRA issued its written order approving the deferred gas cost balances in April 2012.
	In September 2011, we filed an annual report for the twelve months ended June 30, 2011 with the TRA that reflected the transactions in the deferred gas cost account for the ACA mechanism. In March 2012, the TRA approved the deferred gas cost account balances. The TRA issued its written order approving the deferred gas cost balances in April 2012.
	In August 2012, we filed an annual report with the TRA reflecting the shared gas cost savings from gains and losses derived from gas purchase benchmarking and secondary market transactions for the twelve months ended June 30, 2012 under the TIP. In February 2013, the TRA approved the TIP account balances. The TRA issued its written order approving our TIP account balances in March 2013.
	In September 2012, we filed an annual report for the twelve months ended June 30, 2012 with the TRA that reflected the transactions in the deferred gas cost account for the ACA mechanism. In February 2013, the TRA approved the deferred gas cost account balances. The TRA issued its written order approving the deferred gas cost balances in March 2013.
	In August 2013, we filed an annual report with the TRA reflecting the shared gas cost savings from gains and losses derived from gas purchase benchmarking and secondary market transactions for the twelve months ended June 30, 2013 under the TIP. We are waiting on a ruling from the TRA at this time.
	In August 2013, we filed an ACA petition with the TRA to authorize us to make an adjustment to the deferred gas cost account reporting for prior periods in the amount of a $3.7 million under collection. We are waiting on a ruling from the TRA at this time. We intend to file our ACA annual report for the twelve months ended June 30, 2013 upon resolution of this petition.
	In September 2011, we filed a general rate application with the TRA requesting authority for an increase to rates and charges for all customers to produce overall incremental revenues of $16.7 million annually, or 8.9% above then current annual revenues. In addition, the petition also requested modifications of the cost allocation and rate designs underlying our existing rates, including shifting more of our cost recovery to our fixed charges and expanding the period of the WNA to October through April. We also sought approval to implement a school-based energy education program with appropriate cost recovery mechanisms, amortization of certain regulatory assets and deferred accounts, revised depreciation rates for plant and changes to the existing service regulations and tariffs. The changes were proposed to be effective March 1, 2012. In December 2011, we and the Consumer Advocate and Protection Division reached a stipulation and settlement agreement resolving all issues in this proceeding, including an increase in rates and charges to all customers effective March 1, 2012 designed to produce overall incremental revenues of $11.9 million annually, or 6.3% above then current annual revenue, based upon an approved rate of return on equity of 10.2%. The new cost allocation and rate designs shifted recovery of fixed charges from 29% to 37% with a resulting decrease of volumetric charges from 71% to 63%. The stipulation and settlement agreement did not include a cost recovery mechanism for a school-based energy education program. In January 2012, a hearing on this matter was held by the TRA. The TRA approved the settlement agreement at the January 2012 hearing. The TRA's written order was issued in April 2012.
	As a part of the rate case settlement mentioned above, the TRA approved the recovery of $1 million incurred as a result of our response to severe flooding in Nashville in May 2010. These direct incremental expenses had been approved for deferred accounting treatment in October 2010. These deferred expenses are being amortized over 8 years beginning March 1, 2012.
	In August 2013, we filed a petition with the TRA seeking authority to implement an IMR to recover the costs of our capital investments that are made in compliance with federal and state safety and integrity management laws or regulations. We proposed that the rider be effective October 1, 2013 with an initial adjustment on January 1, 2014 of $13.1 million in annual margin revenue from tariff customers based on capital expenditures incurred through October 2013 and for rates to be updated annually outside of general rate cases for the return of and on these capital investments. In September 2013, the TRA issued an order suspending this proposed tariff through December 30, 2013. On November 27, 2013, we filed with the TRA a settlement with the Tennessee Attorney General's Consumer Advocate Division agreeing to the IMR. A hearing on this matter was held December 18, 2013, and the TRA approved the IMR settlement as filed.
	All States
	Due to the seasonal nature of our business, we contract with customers in the secondary market to sell supply and capacity assets when market conditions permit. In North Carolina and South Carolina, we operate under sharing mechanisms approved by the NCUC and the PSCSC for secondary market transactions where 75% of the net margins are flowed through to jurisdictional customers in rates and 25% is retained by us. In Tennessee, we operate under the amended TIP where gas purchase benchmarking gains and losses are combined with secondary market transaction gains and losses and shared 75% by customers and 25% by us. Our share of net gains or losses in Tennessee is subject to an overall annual cap of $1.6 million. In all three jurisdictions for the twelve months ended October 31, 2013, we generated $35.9 million of margin from secondary market activity, $26.9 million of which is allocated to customers as gas cost reductions and $9 million as margin allocated to us. In all three jurisdictions for the twelve months ended October 31, 2012, we generated $38.7 million of margin from secondary market activity, $29 million of which is allocated to customers as gas cost reductions and $9.7 million as margin allocated to us. In all three jurisdictions for the twelve months ended October 31, 2011, we generated $56.1 million of margin from secondary market activity, $42.1 million of which is allocated to customers as gas cost reductions and $14 million as margin allocated to us.
	We currently have commission approval in all three states that place tighter credit requirements on the retail natural gas marketers that schedule gas for transportation service on our system in order to mitigate the risk exposure to the financial condition of the marketers.

Earnings_Per_Share

Earnings Per Share	12 Months Ended
	Oct. 31, 2013
Earnings Per Share of Common Stock	'
Earnings Per Share [Text Block]	'
	3. Earnings Per Share
	We compute basic EPS using the weighted average number of shares of common stock outstanding during each period. Shares of common stock to be issued under approved incentive compensation plans and forward sale agreements are contingently issuable shares, as determined by applying the treasury stock method, and are included in our calculation of fully diluted EPS.
	A reconciliation of basic and diluted EPS for the years ended October 31, 2013, 2012 and 2011 is presented below.
	In thousands except per share amounts	2013		2012		2011
	Net Income	$	134,417	$	119,847	$	113,568
	Average shares of common stock outstanding for basic
	earnings per share		74,884		71,977		72,056
	Contingently issuable shares under incentive compensation plans		289		301		210
	Contingently issuable shares under forward sale agreements		160		-		-
	Average shares of dilutive stock		75,333		72,278		72,266
	Earnings Per Share of Common Stock:
	Basic	$	1.8	$	1.67	$	1.58
	Diluted	$	1.78	$	1.66	$	1.57

Long_Term_Debt

Long Term Debt	12 Months Ended
	Oct. 31, 2013
Long Term Debt Abstract	'
Long Term Debt Text Block	'
	4. Long-Term Debt
	Our long-term debt consists of privately placed senior notes issued under note purchase agreements, as well as publicly issued medium-term and senior notes issued under an indenture. All of our long-term debt is unsecured and is issued at fixed rates. Long-term debt as of October 31, 2013 and 2012 is as follows.
	In thousands	2013		2012
	Senior Notes:
	2.92%, due June 6, 2016	$	40,000	$	40,000
	8.51%, due September 30, 2017		35,000		35,000
	4.24%, due June 6, 2021		160,000		160,000
	3.47%, due July 16, 2027		100,000		100,000
	3.57%, due July 16, 2027		200,000		200,000
	4.65%, due August 1, 2043		300,000		-
	Medium-Term Notes:
	5.00%, due December 19, 2013		100,000		100,000
	6.87%, due October 6, 2023		45,000		45,000
	8.45%, due September 19, 2024		40,000		40,000
	7.40%, due October 3, 2025		55,000		55,000
	7.50%, due October 9, 2026		40,000		40,000
	7.95%, due September 14, 2029		60,000		60,000
	6.00%, due December 19, 2033		100,000		100,000
	Total		1,275,000		975,000
	Less current maturities		100,000		-
	Less discount on issuance of notes		143		-
	Total	$	1,174,857	$	975,000
	Current maturities for the next five years ending October 31 and thereafter are as follows.
	In thousands
	2014	$	100,000
	2015		-
	2016		40,000
	2017		35,000
	2018		-
	Thereafter		1,100,000
	Total	$	1,275,000
	On July 16, 2012, we issued $100 million of senior notes with an interest rate of 3.47%. On October 15, 2012, we issued $200 million of senior notes with an interest rate of 3.57%. Both issuances mature on July 16, 2027. These proceeds were used for general corporate purposes, including the repayment of short-term debt incurred in part for the funding of capital expenditures.
	We have an open combined debt and equity shelf registration statement filed with the SEC in July 2011 that is available for future use until its expiration date of July 6, 2014. Unless otherwise specified at the time such securities are offered for sale, the net proceeds from the sale of the securities will be used for general corporate purposes, including capital expenditures, additions to working capital, advances for or investments in our subsidiaries and for repurchases of shares of our common stock. In February 2013, we sold shares of common stock under this registration statement. For further information on this transaction, see Note 6 to the consolidated financial statements.
	On August 1, 2013, we issued $300 million of thirty-year, unsecured senior notes with an interest rate of 4.65% and at a discount of .048% or $144,000, which we began to amortize ratably over the expected life of the notes, under the registration statement noted above. We have the option to redeem all or part of the notes before the stated maturity prior to February 1, 2043, at a redemption price equal to the greater of a) 100% of the principal amount plus any accrued and unpaid interest to the date of redemption, or b) the sum of the present values of the remaining scheduled payments of principal and interest on the notes to be redeemed, discounted to the date of redemption on a semi-annual basis at the Treasury Rate as defined in the indenture, plus 15 basis points and any accrued and unpaid interest to the date of redemption. We have the option to redeem all or part of the notes before the stated maturity on or after February 1, 2043, at 100% of the principal amount plus any accrued and unpaid interest to the date of redemption. We used the net proceeds of $297.2 million from this issuance to finance capital expenditures, to repay $100 million of our 5% medium-term notes due December 19, 2013 at maturity, to repay outstanding short-term, unsecured notes under our commercial paper (CP) program and for general corporate purposes.
	The amount of cash dividends that may be paid on common stock is restricted by provisions contained in certain note agreements under which long-term debt was issued, with those for the senior notes being the most restrictive. We cannot pay or declare any dividends or make any other distribution on any class of stock or make any investments in subsidiaries or permit any subsidiary to do any of the above (all of the foregoing being “restricted payments”), except out of net earnings available for restricted payments. As of October 31, 2013, our retained earnings were not restricted as the amount available for restricted payments was greater than our actual retained earnings as presented below.
	In thousands
	Amount available for restricted payments	$	760,870
	Retained earnings		627,236
	We are subject to default provisions related to our long-term debt and short-term borrowings. Failure to satisfy any of the default provisions may result in total outstanding issues of debt becoming due. There are cross default provisions in all of our debt agreements. As of October 31, 2013, we are in compliance with all default provisions.
	The default provisions of some or all of our senior debt include:
	Failure to make principal or interest payments,
	Bankruptcy, liquidation or insolvency,
	Final judgment against us in excess of $1 million that after 60 days is not discharged, satisfied or stayed pending appeal,
	Specified events under the Employee Retirement Income Security Act of 1974,
	Change in control, and
	Failure to observe or perform covenants, including:
	Interest coverage of at least 1.75 times. Interest coverage was 4.6 times as of October 31, 2013;
	Funded debt cannot exceed 70% of total capitalization. Funded debt was 59% of total capitalization as of October 31, 2013;
	Funded debt of all subsidiaries in the aggregate cannot exceed 15% of total capitalization. There is no funded debt of our subsidiaries as of October 31, 2013;
	Restrictions on permitted liens;
	Restrictions on paying dividends, on or repurchasing our stock or making investments in subsidiaries; and
	Restrictions on burdensome agreements.

Short_Term_Debt

Short Term Debt	12 Months Ended
	Oct. 31, 2013
Short Term Debt Disclosure [Abstract]	'
Short Term Debt Text Block	'
	5. Short-Term Debt Instruments
	We have a $650 million five-year revolving syndicated credit facility that expires on October 1, 2017. The facility has an option to request an expansion of up to $850 million. On November 1, 2013, we entered into an agreement with the lenders under the facility which increased our borrowing capacity to $850 million. We pay an annual fee of $35,000 plus 8.5 basis points for any unused amount. The facility provides a line of credit for letters of credit of $10 million, of which $2.1 million and $3.6 million were issued and outstanding at October 31, 2013 and 2012, respectively. These letters of credit are used to guarantee claims from self-insurance under our general and automobile liability policies. The credit facility bears interest based on the 30-day London Interbank Offered Rate (LIBOR) plus from 75 to 125 basis points, based on our credit ratings. Amounts borrowed are continuously renewable until the expiration of the facility in 2017 provided that we are in compliance with all terms of the agreement. See Note 4 to the consolidated financial statements for discussion of default provisions, including cross default provisions, in all of our debt agreements.
	We have a $650 million unsecured CP program that is backstopped by the revolving syndicated credit facility. In conjunction with the exercise of the option in November 2013, the amounts outstanding under the revolving syndicated credit facility and the CP program, either individually or in the aggregate, have been increased to, but cannot exceed, $850 million. The notes issued under the CP program may have maturities not to exceed 397 days from the date of issuance and bear interest based on, among other things, the size and maturity date of the note, the frequency of the issuance and our credit ratings, plus a spread of 5 basis points. Any borrowings under the CP program rank equally with our other unsubordinated and unsecured debt. The notes under the CP program are not registered and are offered and issued pursuant to an exemption from registration. Due to the seasonal nature of our business, amounts borrowed can vary significantly during the year.
	As of October 31, 2013, we have $400 million of notes outstanding under the CP program, as included in “Short-term debt” in “Current Liabilities” in the Consolidated Balance Sheets, with original maturities ranging from 1 to 37 days from their dates of issuance at a weighted average interest rate of .36%. As of October 31, 2012, our outstanding notes under the CP program, included in the Consolidated Balance Sheets as stated above, were $365 million at a weighted average interest rate of .42%.
	A summary of the short-term debt activity for the twelve months ended October 31, 2013 is as follows.
		Short-Term Debt Activity
			Credit			Commercial			Total
	In thousands		Facility			Paper			Borrowings
		Minimum amount outstanding (1)	$	-		$	220,000		$	220,000
		Maximum amount outstanding (1)	$	10,000		$	555,000		$	555,000
		Minimum interest rate (2)		1.12	%		0.23	%		0.23	%
		Maximum interest rate		1.12	%		0.45	%		1.12	%
		Weighted average interest rate		1.12	%		0.32	%		0.32	%
		(1) During December 2012, we were borrowing under both the credit facility and CP program for a portion of the month.
		(2) This is the minimum rate when we were borrowing under the credit facility and/or CP program.
	Our five-year revolving syndicated credit facility's financial covenants require us to maintain a ratio of total debt to total capitalization of no greater than 70%, and our actual ratio was 59% at October 31, 2013.

Stockholders_Equity

Stockholders' Equity	12 Months Ended
	Oct. 31, 2013
Stockholders' Equity [Abstract]	'
Stockholders' Equity [Text Block]	'
	6. Stockholders' Equity
	Capital Stock
	Changes in common stock for the years ended October 31, 2013, 2012 and 2011 are as follows.
	In thousands	Shares		Amount
	Balance, October 31, 2010	72,282		$	445,640
	Issued to participants in the Employee Stock Purchase Plan (ESPP)	30			870
	Issued to the Dividend Reinvestment and Stock Purchase Plan (DRIP)	657			18,834
	Issued to participants in the Incentive Compensation Plan (ICP)	149			4,451
	Shares repurchased under Accelerated Share Repurchase (ASR) agreement	-800			-23,004
	Balance, October 31, 2011	72,318			446,791
	Issued to ESPP	30			894
	Issued to DRIP	677			20,508
	Issued to ICP	25			796
	Shares repurchased under ASR agreement	-800			-26,528
	Balance, October 31, 2012	72,250			442,461
	Issued to ESPP	33			1,056
	Issued to DRIP	720			22,791
	Issued to ICP	96			3,065
	Issuance of common stock through public share offering, net of underwriting fees	3,000			92,640
	Costs from issuance of common stock	-			-369
	Balance, October 31, 2013	76,099		$	561,644
	In June 2004, the Board of Directors approved a Common Stock Open Market Purchase Program that authorized the repurchase of up to three million shares of currently outstanding shares of common stock. We implemented the program in September 2004. We utilize a broker to repurchase the shares on the open market, and such shares are cancelled and become authorized but unissued shares available for issuance under the ESPP, DRIP and ICP.
	On December 16, 2005, the Board of Directors approved an increase in the number of shares in this program from three million to six million to reflect the two-for-one stock split in 2004. The Board also approved at that time an amendment of the Common Stock Open Market Purchase Program to provide for the repurchase of up to four million additional shares of common stock to maintain our debt-to-equity capitalization ratios at target levels. These combined actions increased the total authorized share repurchases from three million to ten million shares. The additional four million shares were referred to as our ASR program. On March 6, 2009, the Board of Directors authorized the repurchase of up to an additional four million shares under the Common Stock Open Market Purchase Program and the ASR program, which were consolidated.
	On January 29, 2013, we entered into an underwriting agreement under our open combined debt and equity shelf registration statement to sell up to 4.6 million shares of our common stock as follows.
	Direct shares – 3 million shares were issued by us and delivered directly to the underwriters with settlement on February 4, 2013. We received $92.6 million from the underwriters and recorded this amount in “Stockholders' equity” as an addition to “Common stock” in the Consolidated Balance Sheets. The shares were purchased by the underwriters at the net price of $30.88 per share, the offering price to the public of $32 per share per the prospectus less an underwriting discount of $1.12 per share. The net proceeds from this sale of our common stock were used to repay outstanding short-term, unsecured notes under our CP program.
	Forward shares – 1 million shares were borrowed by a forward counterparty and sold to the underwriters for resale to the public on February 4, 2013. Under this initial forward sale agreement (FSA) that we executed with the forward counterparty on January 29, 2013, we agreed to sell 1 million shares to the forward counterparty at the same price as the direct shares to be settled no later than mid December 2013. Under the terms of this FSA, at our election, we may physically settle in shares, cash or net share settle for all or a portion of our obligation under the agreement.
	Additional shares – Up to .6 million shares were subject to a 30-day option by the underwriters to purchase these additional shares at the same price as the direct shares and would be, at our option, either issued at the time of purchase and delivered directly to the underwriters or borrowed and delivered to the underwriters by the forward counterparty. On February 19, 2013, the underwriters exercised their option to purchase the full additional .6 million shares of our common stock at the net price described above of $30.88 per share with settlement on February 22, 2013. We elected to place the .6 million shares under an additional FSA having substantially similar terms as the original FSA, including settlement options at our election as described above. In connection with the additional FSA, the .6 million shares were borrowed from third parties and sold to the underwriters by the forward counterparty.
	On December 16, 2013, we physically settled the FSAs by issuing 1.6 million shares of our common stock to the forward counterparty and received net proceeds of $47.3 million based on the net settlement price of $30.88 per share, the original offering price, less certain adjustments. Upon settlement, we used the net proceeds from these FSA transactions to finance capital expenditures, repay outstanding short-term, unsecured notes under our CP program and for general corporate purposes.
	In accordance with ASC 815-40, Derivatives and Hedging - Contracts in Entity's Own Equity, we have classified the FSAs as equity transactions because the forward sale transactions are indexed to our own stock and physical settlement is within our control. As a result of this classification, no amounts were recorded in the consolidated financial statements until settlement of each FSA.
	Upon physical settlement of the FSAs, delivery of our shares resulted in dilution to our EPS at the date of the settlement. In quarters prior to the settlement date, any dilutive effect of the FSAs on our EPS occurred during periods when the average market price per share of our common stock was above the per share adjusted forward sale price described above. See Note 3 to the consolidated financial statements for the dilutive effect of the FSAs on our EPS at October 31, 2013 with the inclusion of incremental shares in our average shares of dilutive stock as calculated under the treasury stock method.
	On January 4, 2012, we entered into an ASR agreement where we purchased 800,000 shares of our common stock from an investment bank at the closing price that day of $33.77 per share. The settlement and retirement of those shares occurred on January 5, 2012. Total consideration paid to purchase the shares of $27 million was recorded in “Stockholders' equity” as a reduction in “Common stock” in the Consolidated Balance Sheets.
	As part of the ASR, we simultaneously entered into a forward sale contract with the investment bank that was expected to mature in 52 trading days, or March 21, 2012. Under the terms of the forward sale contract, the investment bank was required to purchase, in the open market, 800,000 shares of our common stock during the term of the contract to fulfill its obligation related to the shares it borrowed from third parties and sold to us. At settlement, we, at our option, were required to either pay cash or issue shares of our common stock to the investment bank if the investment bank's weighted average purchase price, less a $.09 per share discount, was higher than the January 4, 2012 closing price. The investment bank was required to pay us either cash or shares of our common stock, at our option, if the investment bank's weighted average price, less a $.09 per share discount, for the shares purchased was lower than the initial purchase closing price. At settlement on February 28, 2012, we received $.5 million from the investment bank and recorded this amount in “Stockholders' equity” as an addition to “Common stock” in the Consolidated Balance Sheets. The $.5 million was the difference between the investment bank's weighted average purchase price of $33.25 per share less a discount of $.09 per share for a settlement price of $33.16 per share and the initial purchase closing price of $33.77 per share multiplied by 800,000 shares. We had an ASR transaction in 2011 as presented in the table above with a similar structure with the investment bank, which were accounted for in the same manner.
	As of October 31, 2013, our shares of common stock were reserved for issuance as follows.
	In thousands
	ESPP	210
	DRIP	1,538
	ICP	1,050
	Total	2,798
	Other Comprehensive Income (Loss)
	OCIL is a part of our accumulated OCIL and is comprised of hedging activities from our equity method investments. For further information on these hedging activities by our equity method investments, see Note 12 to the consolidated financial statements. Changes in each component of accumulated OCIL are presented below for the years ended October 31, 2013 and 2012.
	Changes in Accumulated OCIL (1)
	In thousands
	Balance, October 31, 2011		$	-452
	OCIL before reclassifications, net of tax			-826
	Amounts reclassified from accumulated OCIL, net of tax			973
	Total current period activity, net of tax			147
	Balance, October 31, 2012			-305
	OCIL before reclassifications, net of tax			-109
	Amounts reclassified from accumulated OCIL, net of tax			130
	Total current period activity, net of tax			21
	Balance, October 31, 2013		$	-284
	(1) Amounts in parentheses indicate debits to accumulated OCIL.
	A reconciliation of the effect on certain line items of net income on amounts reclassified out of each component of accumulated OCIL is presented below for the years ended October 31, 2013 and 2012.
		Reclassifications Out of
		Accumulated OCIL (1)
		Years Ended
		October 31,					Affected Line Items on Statement of
	In thousands	2013			2012		Comprehensive Income
	Hedging activities of equity method investments	$	-215		$	-1,594	Income from equity method investments
	Income tax expense		85			621	Income taxes
	Total reclassification for the period, net of tax	$	-130		$	-973
	(1) Amounts in parentheses indicate credits to accumulated OCIL.

Financial_Instruments_Risk_Man

Financial Instruments & Risk Management	12 Months Ended
	Oct. 31, 2013
Financial Instruments And Risk Management Disclosure [Abstract]	'
Financial Instruments And Risk Management [Text Block]	'
	7. Financial Instruments and Related Fair Value
	Derivative Assets and Liabilities under Master Netting Arrangements
	We maintain brokerage accounts to facilitate transactions that support our gas cost hedging plans. The accounting guidance related to derivatives and hedging requires that we use a gross presentation, based on our election, for the fair value amounts of our derivative instruments. We use long position gas purchase options to provide some level of protection for our customers in the event of significant commodity price increases. As of October 31, 2013 and 2012, we had long gas purchase options providing total coverage of 25.4 million dekatherms and 35.8 million dekatherms, respectively. The long gas purchase options held at October 31, 2013 are for the period from December 2013 through October 2014.
	Fair Value Measurements
	We use financial instruments that are not designated as hedges for accounting purposes to mitigate commodity price risk for our customers. We also have marketable securities that are held in rabbi trusts established for certain of our deferred compensation plans. In developing our fair value measurements of these financial instruments, we utilize market data or assumptions about risk and the risks inherent in the inputs to the valuation technique. Fair value refers to the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants in the market in which the entity transacts. We classify fair value balances based on the observance of those inputs into the fair value hierarchy levels as set forth in the fair value accounting guidance and fully described in “Fair Value Measurements” in Note 1 to the consolidated financial statements.
	The following table sets forth, by level of the fair value hierarchy, our financial assets and liabilities that were accounted for at fair value on a recurring basis as of October 31, 2013 and 2012. Financial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. Our assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the valuation of fair value assets and liabilities and their consideration within the fair value hierarchy levels. We have had no transfers between any level during the years ended October 31, 2013 and 2012.
	Recurring Fair Value Measurements as of October 31, 2013
					Significant
			Quoted Prices		Other			Significant
			in Active		Observable			Unobservable		Total
			Markets		Inputs			Inputs		Carrying
	In thousands		(Level 1)		(Level 2)			(Level 3)		Value
	Assets:
	Derivatives held for distribution operations	$	1,834	$	-		$	-	$	1,834
	Debt and equity securities held as trading securities:
	Money markets		380		-			-		380
	Mutual funds		2,814		-			-		2,814
	Total fair value assets	$	5,028	$	-		$	-	$	5,028
	Recurring Fair Value Measurements as of October 31, 2012
					Significant
			Quoted Prices		Other			Significant
			in Active		Observable			Unobservable		Total
			Markets		Inputs			Inputs		Carrying
	In thousands		(Level 1)		(Level 2)			(Level 3)		Value
	Assets:
	Derivatives held for distribution operations	$	3,153	$	-		$	-	$	3,153
	Debt and equity securities held as trading securities:
	Money markets		243		-			-		243
	Mutual funds		2,045		-			-		2,045
	Total fair value assets	$	5,441	$	-		$	-	$	5,441
	Our utility segment derivative instruments are used in accordance with programs filed with or approved by the NCUC, the PSCSC and the TRA to hedge the impact of market fluctuations in natural gas prices. These derivative instruments are accounted for at fair value each reporting period. In accordance with regulatory requirements, the net gains and losses related to these derivatives are reflected in purchased gas costs and ultimately passed through to customers through our PGA procedures. In accordance with accounting provisions for rate-regulated activities, the unrecovered amounts related to these instruments are reflected as a regulatory asset or liability, as appropriate, in “Amounts due from customers” or “Amounts due to customers” in Note 1 to the consolidated financial statements. These derivative instruments are exchange-traded derivative contracts. Exchange-traded contracts are generally based on unadjusted quoted prices in active markets and are classified within Level 1.
	Trading securities include assets in rabbi trusts established for our deferred compensation plans and are included in “Marketable securities, at fair value” in “Noncurrent Assets” in the Consolidated Balance Sheets. Securities classified within Level 1 include funds held in money market and mutual funds which are highly liquid and are actively traded on the exchanges.
	Our long-term debt is recorded at unamortized cost. In developing the fair value of our long-term debt, we use a discounted cash flow technique, consistently applied, that incorporates a developed discount rate using long-term debt similarly rated by credit rating agencies combined with the U.S. Treasury benchmark with consideration given to maturities, redemption terms and credit ratings similar to our debt issuances. The carrying amount and fair value of our long-term debt, including the current portion, which is classified within Level 2, are shown below.
			Carrying
	In thousands		Amount		Fair Value
	As of October 31, 2013	$	1,275,000	$	1,409,892
	As of October 31, 2012		975,000		1,163,227
	Quantitative and Qualitative Disclosures
	The costs of our financial price hedging options for natural gas and all other costs related to hedging activities of our regulated gas costs are recorded in accordance with our regulatory tariffs approved by our state regulatory commissions, and thus are not accounted for as designated hedging instruments under derivative accounting standards. As required by the accounting guidance, the fair value amounts are presented on a gross basis and do not reflect any netting of asset and liability amounts or cash collateral amounts under master netting arrangements.
	The following table presents the fair value and balance sheet classification of our financial options for natural gas as of October 31, 2013 and 2012.
	Fair Value of Derivative Instruments
	In thousands					2013				2012
	Derivatives Not Designated as Hedging Instruments under Derivative Accounting Standards:
	Asset Financial Instruments:
	Current Assets - Gas purchase derivative assets (December 2013 - October 2014)					$	1,834
	Current Assets - Gas purchase derivative assets (December 2012 - October 2013)								$	3,153
	We purchase natural gas for our regulated operations for resale under tariffs approved by state regulatory commissions. We recover the cost of gas purchased for regulated operations through PGA procedures. Our risk management policies allow us to use financial instruments to hedge commodity price risks, but not for speculative trading. The strategy and objective of our hedging programs is to use these financial instruments to provide some level of protection against significant price increases. Accordingly, the operation of the hedging programs on the regulated utility segment as a result of the use of these financial derivatives is initially deferred as amounts due to/from customers included as “Regulatory Assets” or “Regulatory Liabilities” in Note 1 to the consolidated financial statements and recognized in the Consolidated Statements of Comprehensive Income as a component of “Cost of Gas” when the related costs are recovered through our rates.
	The following table presents the impact that financial instruments not designated as hedging instruments under derivative accounting standards would have had on the Consolidated Statements of Comprehensive Income for the twelve months ended October 31, 2013 and 2012, absent the regulatory treatment under our approved PGA procedures.
											Location of Loss
		Amount of Loss Recognized					Amount of Loss Deferred				Recognized through
	In thousands	on Derivative Instruments					Under PGA Procedures				PGA Procedures
			Twelve Months Ended					Twelve Months Ended
			31-Oct					31-Oct
			2013		2012			2013		2012
	Gas purchase options	$	6,303	$	8		$	6,303	$	8	Cost of Gas
	In Tennessee, the cost of gas purchase options and all other costs related to hedging activities up to 1% of total annual gas costs are approved for recovery under the terms and conditions of our TIP approved by the TRA. In South Carolina, the costs of gas purchase options are subject to and are approved for recovery under the terms and conditions of our gas hedging plan approved by the PSCSC. In North Carolina, the costs associated with our hedging program are treated as gas costs subject to an annual cost review proceeding by the NCUC.
	Credit and Counterparty Risk
	We are exposed to credit risk as a result of transactions for the purchase and sale of products and services and management agreements of our transportation capacity, storage capacity and supply contracts with major companies in the energy industry and within our utility operations serving industrial, commercial, power generation, residential and municipal energy consumers. These transactions principally occur in the eastern, gulf coast and mid-west regions of the United States. We believe that this geographic concentration does not contribute significantly to our overall exposure to credit risk. Credit risk associated with trade accounts receivable for the natural gas distribution segment is mitigated by the large number of individual customers and diversity in our customer base.
	We enter into contracts with third parties to buy and sell natural gas. A significant portion of these transactions are with, or are associated with, energy producers, utility companies, off-system municipalities and natural gas marketers. The amount included in “Trade accounts receivable” in “Current Assets” in the Consolidated Balance Sheets attributable to these entities amounted to $13.4 million, or approximately 17% of our gross trade accounts receivable at October 31, 2013. Our policy requires counterparties to have an investment-grade credit rating at the time of the contract, or in situations where counterparties do not have investment grade or functionally equivalent credit ratings, our policy requires credit enhancements that include letters of credit or parental guaranties. In either circumstance, the policy specifies limits on the contract amount and duration based on the counterparty's credit rating and/or credit support. In order to minimize our exposure, we continually re-evaluate third-party creditworthiness and market conditions and modify our requirements accordingly.
	We also enter into contracts with third parties to manage some of our supply and capacity assets for the purpose of maximizing their value. These arrangements include a counterparty credit evaluation according to our policy described above prior to contract execution and typically have durations of one year or less. In the event that a party is unable to perform under these arrangements, we have exposure to satisfy our underlying supply or demand contractual obligations that were incurred while under the management of this third party. We believe, based on our credit policies as of October 31, 2013, that our financial position, results of operations and cash flows will not be materially affected as a result of nonperformance by any single counterparty.
	Natural gas distribution operating revenues and related trade accounts receivable are generated from state-regulated utility natural gas sales and transportation to over one million residential, commercial and industrial customers, including power generation and municipal customers, located in North Carolina, South Carolina and Tennessee. A change in economic conditions may affect the ability of customers to meet their obligations. We have mitigated our exposure to the risk of non-payment of utility bills by our customers. Gas costs related to uncollectible accounts are recovered through PGA procedures in all jurisdictions. To manage the non-gas cost customer credit risk, we evaluate credit quality and payment history and may require cash deposits from our high risk customers that do not satisfy our predetermined credit standards until a satisfactory payment history has been established. Significant increases in the price of natural gas and colder-than-normal weather can slow our collection efforts as customers experience increased difficulty in paying their gas bills, leading to higher than normal trade accounts receivable; however, we believe that our provision for possible losses on uncollectible trade accounts receivable is adequate for our credit loss exposure.
	Risk Management
	Our financial derivative instruments do not contain material credit-risk-related or other contingent features that could require us to make accelerated payments.
We seek to identify, assess, monitor and manage risk in accordance with defined policies and procedures under an Enterprise Risk Management program. In addition, we have an Energy Price Risk Management Committee that monitors compliance with our hedging programs, policies and procedures.

Commitment_Contingencies

Commitment & Contingencies	12 Months Ended
	Oct. 31, 2013
Commitments and Contingencies Disclosure [Abstract]	'
Commitments And Contingencies Disclosure Text Block	'
	8. Commitments and Contingent Liabilities
	Leases
	We lease certain buildings, land and equipment for use in our operations under noncancelable operating leases. We account for these leases by recognizing the future minimum lease payments as expense on a straight-line basis over the respective minimum lease terms under current accounting guidance.
	Operating lease payments for the years ended October 31, 2013, 2012 and 2011 are as follows.
	In thousands		2013			2012			2011
	Operating lease payments (1)		$	4,729		$	3,712		$	4,496
	(1) Operating lease payments do not include payments for common area maintenance, utilities or tax payments.
	Future minimum lease obligations for the next five years ending October 31 and thereafter are as follows.
	In thousands
	2014	$	4,543
	2015		4,592
	2016		4,491
	2017		4,297
	2018		4,225
	Thereafter		31,496
	Total	$	53,644
	Long-term contracts
	We routinely enter into long-term gas supply commodity and capacity commitments and other agreements that commit future cash flows to acquire services we need in our business. These commitments include pipeline and storage capacity contracts and gas supply contracts to provide service to our customers and telecommunication and information technology contracts and other purchase obligations. Costs arising from the gas supply commodity and capacity commitments, while significant, are pass-through costs to our customers and are generally fully recoverable through our PGA procedures and prudence reviews in North Carolina and South Carolina and under the TIP in Tennessee. The time periods for pipeline and storage capacity contracts are up to twenty-two years. The time periods for gas supply contracts are up to one year. The time periods for the telecommunications and technology outsourcing contracts, maintenance fees for hardware and software applications, usage fees, local and long-distance costs and wireless service are up to three years. Other purchase obligations consist primarily of commitments for pipeline products, vehicles, equipment and contractors.
	Certain storage and pipeline capacity contracts require the payment of demand charges that are based on rates approved by the FERC in order to maintain our right to access the natural gas storage or the pipeline capacity on a firm basis during the contract term. The demand charges that are incurred in each period are recognized in the Consolidated Statements of Comprehensive Income as part of gas purchases and included in “Cost of Gas.”
	As of October 31, 2013, future unconditional purchase obligations for the next five years ending October 31 and thereafter are as follows.
		Pipeline and						Telecommunications
		Storage						and Information
	In thousands	Capacity			Gas Supply			Technology			Other		Total
	2014	$	170,430		$	6,356		$	11,045		$	24,951	$	212,782
	2015		157,407			-			4,676			-		162,083
	2016		150,544			-			760			-		151,304
	2017		145,494			-			-			-		145,494
	2018		142,983			-			-			-		142,983
	Thereafter		781,549			-			-			-		781,549
	Total	$	1,548,407		$	6,356		$	16,481		$	24,951	$	1,596,195
	Legal
	We have only routine litigation in the normal course of business. We do not expect any of these routine litigation matters to have a material effect on our financial position, results of operations or cash flows.
	Letters of Credit
	We use letters of credit to guarantee claims from self-insurance under our general and automobile liability policies. We had $2.1 million in letters of credit that were issued and outstanding at October 31, 2013. Additional information concerning letters of credit is included in Note 5 to the consolidated financial statements.
	Environmental Matters
	Our three regulatory commissions have authorized us to utilize deferral accounting in connection with environmental costs. Accordingly, we have established regulatory assets for actual environmental costs incurred and for estimated environmental liabilities recorded.
	In 1997, we entered into a settlement with a third-party with respect to nine manufactured gas plant (MGP) sites that we have owned, leased or operated that released us from any investigation and remediation liability. Although no such claims are pending or, to our knowledge, threatened, the settlement did not cover any third-party claims for personal injury, death, property damage and diminution of property value or natural resources.
	In connection with the 2003 North Carolina Natural Gas Corporation (NCNG) acquisition, several MGP sites owned by NCNG were transferred to a wholly owned subsidiary of Progress Energy, Inc. (Progress), now a subsidiary of Duke Energy Corporation (DEC), prior to closing. Progress has complete responsibility for performing all of NCNG's remediation obligations to conduct testing and clean-up at these sites, including both the costs of such testing and clean-up and the implementation of any affirmative remediation obligations that NCNG has related to the sites. Progress' responsibility does not include any third-party claims for personal injury, death, property damage, and diminution of property value or natural resources. We know of no such pending or threatened claims.
	There are four other MGP sites located in Reidsville and Hickory, North Carolina, Nashville, Tennessee and Anderson, South Carolina that we have owned, leased or operated and for which we have an investigation and remediation liability. In fiscal year 2012, we performed soil remediation work at our Reidsville site. In July 2012, the North Carolina Department of Environment and Natural Resources (NCDENR) approved our proposed groundwater investigation work plan, which included installing five monitoring wells in September 2012. The NCDENR is no longer requiring the groundwater remedial action plan. We filed land use restrictions on the property with the NCDENR in the fourth quarter of our fiscal year 2013. Upon NCDENR's completed review, we will file land use restrictions with the Register of Deeds for Reidsville, North Carolina. We have incurred $.6 million of remediation costs at the Reidsville site through October 31, 2013.
	As part of a voluntary agreement with the NCDENR, we conducted and completed soil remediation for the Hickory, North Carolina MGP site in 2010. A Phase II groundwater investigation was conducted in 2011. A groundwater remedial action plan was submitted and approved by NCDENR in 2012. We continue to conduct quarterly groundwater monitoring at this site in accordance with our site remediation plan. NCDENR has approved land use restrictions on this site. Once we obtain the property owner's signature, we will then file land use restrictions with the Register of Deeds for Hickory, North Carolina. We have incurred $1.5 million of remediation costs at this site through October 31, 2013.
	In November 2008, we submitted our final report of the remediation of the Nashville MGP holding tank site to the Tennessee Department of Environment and Conservation (TDEC). Remediation has been completed, and a final consent order imposing land usage restrictions on the property was approved and signed by the TDEC in June 2010. The final consent order required two years of semi-annual groundwater monitoring, which has been completed. We have incurred $1.5 million of remediation costs at this site through October 31, 2013.
	During 2008, we became aware of and began investigating soil and groundwater molecular sieve contamination concerns at our Huntersville LNG facility. The molecular sieve and the related contaminated soil were removed and properly disposed, and in June 2010, we received a determination letter from the NCDENR that no further soil remediation would be required at the site for this issue. In September 2011, we received a letter from the NCDENR indicating their desire to enter into an Administrative Consent Order (ACO) addressing the remaining groundwater issues at the site. On April 11, 2012, we entered into a no admit/no deny ACO that imposed a fine of $40,000, unpaid annual fees totaling $18,000 and investigative and administrative costs of $1,860. As part of the ACO, we are required to develop a site assessment plan to determine the extent of the groundwater contamination related to the sieve burial, a groundwater remediation strategy and a groundwater and surface water site-wide monitoring program. A site assessment plan was accepted by the NCDENR, and we began groundwater sampling in July 2012. We performed an initial round of sampling in November and December 2012 which was inconclusive as to migration, and thus additional groundwater monitoring wells were installed during March 2013 to aid in determining the extent of the groundwater contamination. The groundwater sampling results were submitted to the NCDENR in October 2013, and based on their response, we may be required to submit additional plan(s) to remediate and/or monitor the groundwater.
	The Huntersville LNG facility was originally coated with lead-based paint. To avoid lead-based paint exposure or ground contamination, removal of lead-based paint from the site was initiated in spring 2010. The last phase of the lead-based paint removal began in July 2012 on the LNG tank, and the remediation of rafters in a nearby building began in the fourth quarter of our fiscal year 2013 with completion anticipated for both projects by the end of fiscal 2014. We have incurred $4.6 million of remediation costs through October 31, 2013 for all issues at the Huntersville LNG plant site.
	Our Nashville LNG facility was also originally coated with lead-based paint. We completed the remediation of the facility in May 2012 and incurred $.5 million of remediation costs.
	We have transitioned away from owning and maintaining our own petroleum underground storage tanks (USTs) with the exception of our Charlotte, North Carolina resource center which continues to operate two USTs. During 2011, our Greenville, South Carolina and Greensboro and Salisbury, North Carolina resource centers had their tanks removed, and we do not anticipate significant environmental remediation with respect to those removals. The South Carolina Department of Health and Environmental Control (SCDHEC) requested that we conduct an initial groundwater assessment at our Greenville, South Carolina site to determine its current groundwater quality condition. This assessment was conducted in August 2012, and in November 2012, we received a determination letter from the SCDHEC that no further groundwater remediation would be required at the site for this issue.
	In July 2005, we were notified by the NCDENR that we were named as a potentially responsible party for alleged environmental issues associated with a propane UST site in Clemmons, North Carolina. We owned and operated this site from March 1986 until June 1988 in connection with a non-utility venture. There have been at least four owners of the site. We contend that we contractually transferred any and all clean-up costs to the new owner of the site when we sold this venture in June 1988. However, the owners that purchased the property contend that we only transferred the clean-up costs associated with the gasoline pumps and not the USTs. It is unclear of the outcome of this case and how many of the former owners may ultimately be responsible for this site. Based on the uncertainty of the ultimate liability, we established an immaterial non-regulated environmental liability for one-fourth of the estimated cost to remediate the site.
	One of our resource centers has coatings containing asbestos on some of their pipelines. We have educated our employees on the hazards of asbestos and implemented procedures for removing these coatings from our pipelines when we must excavate and expose portions of the pipeline, which generally occur only in small increments.
	For all the matters discussed above, as of October 31, 2013, our estimated undiscounted environmental liability totaled $1.3 million, and consisted of $1.1 million for the MGP sites for which we retain remediation responsibility, $.1 million for the groundwater remediation at the Huntersville LNG site, and $.1 million for the LNG facilities and USTs not yet remediated. The costs we reasonably expect to incur are estimated using assumptions based on actual costs incurred, the timing of future payments and inflation factors, among others.
	As of October 31, 2013, our regulatory assets for unamortized environmental costs in our three-state territory totaled $9.4 million. We received approval from the TRA to recover $2 million of our deferred Tennessee environmental costs over an eight-year period beginning March 2012, pursuant to the 2012 general rate case proceeding in Tennessee. We will seek recovery of the remaining Tennessee balance in future rate proceedings. The approval by the NCUC in December 2013 of the settlement of the general rate proceeding approves recovery of $6.3 million of our deferred North Carolina environmental costs over a five-year period beginning January 2014. We received approval from the PSCSC to recover $.2 million of our deferred South Carolina environmental costs over a one-year period beginning November 2013, pursuant to the annual rate stabilization order dated October 2013. For further information on regulatory matters, see Note 2 to the consolidated financial statements.
	Further evaluation of the MGP, LNG and UST sites and removal of lead-based paint at our LNG site could significantly affect recorded amounts; however, we believe that the ultimate resolution of these matters will not have a material effect on our financial position, results of operations or cash flows.

Employee_Benefit_Plans

Employee Benefit Plans	12 Months Ended
	Oct. 31, 2013
Employee Benefit Plans Disclosure [Abstract]	'
Pension And Other Postretirement Benefits Disclosure Text Block	'
	9. Employee Benefit Plans
	Under accounting guidance, we are required to recognize all obligations related to defined benefit pension and other postretirement employee benefits (OPEB) plans and quantify the plans' funded status as an asset or liability on the Consolidated Balance Sheets. In accordance with accounting guidance, we measure the plans' assets and obligations that determine our funded status as of the end of our fiscal year, October 31. We are required to recognize as a component of OCI the changes in the funded status that occurred during the year that are not recognized as part of net periodic benefit cost; however, in 2006, we obtained regulatory treatment from the NCUC, the PSCSC and the TRA to record the amount that would have been recorded in accumulated OCI as a regulatory asset or liability as the future recovery of pension and OPEB costs is probable. To date, our regulators have allowed future recovery of our pension and OPEB costs. For the impact of this regulatory treatment, see the following table of actuarial plan information that specifies the amounts not yet recognized as a component of cost and recognized as a regulatory asset or liability. Our plans' assets are required to be accounted for at fair value.
	Pension Benefits
	We have a noncontributory, tax-qualified defined benefit pension plan (qualified pension plan) for our eligible employees. A defined benefit plan specifies the amount of benefit that an eligible participant eventually will receive upon retirement using information about that participant. An employee became eligible on the January 1 or July 1 following either the date on which he or she attained age 30 or attained age 21 and completed 1,000 hours of service during the 12-month period commencing on the employment date. Plan benefits are generally based on credited years of service and the level of compensation during the five consecutive years of the last ten years prior to retirement or termination during which the participant received the highest compensation. Our policy is to fund the plan in an amount not in excess of the amount that is deductible for income tax purposes. The qualified pension plan is closed to employees hired after December 31, 2007. Employees hired prior to January 1, 2008 continue to participate in the qualified pension plan. Employees are vested after five years of service and can be credited with up to a total of 35 years of service. When a vested employee leaves the company, his benefit payment will be calculated as the greater of the accrued benefit as of December 31, 2007 under a specific formula plus the accrued benefit calculated under a second formula for years of service after December 31, 2007, or the benefit for all years of service up to 35 years under the second formula.
	The investment objectives of the qualified pension plan are oriented to meet both the current ongoing and future commitments to the participants and designed to grow at an acceptable rate of return for the risks permitted under the investment policy guidelines. Assets are structured to provide for both short-term and long-term needs and to meet the objectives of the qualified pension plan as specified by the Benefits Committee of the Board of Directors.
	Our primary investment objective of the qualified pension plan is to generate sufficient assets to meet plan liabilities. The plan's assets will therefore be invested to maximize long-term returns in a manner that is consistent with the plan's liabilities, cash flow requirements and risk tolerance. The plan's liabilities are defined in terms of participant salaries. Given the nature of these liabilities and recognizing the long-term benefits of investing in return-generating assets, the qualified pension plan seeks to invest in a diversified portfolio to:
	Achieve full funding over the longer term, and
	Control year-to-year fluctuations in pension expense that is created by asset and liability volatility.
	We consider the historical long-term return experience of our assets, the current and targeted allocation of our plan assets and the expected long-term rates of return. Investment advisors assist us in deriving expected long-term rates of return. These rates are generally based on a 20-year horizon for various asset classes, our expected investments of plan assets and active asset management instead of a passive investment strategy of an index fund.
	The investment philosophy of the qualified pension plan is to maintain a balanced portfolio which is diversified across asset classes. The portfolio is primarily composed of equity and fixed income investments in order to provide diversification as to issuers, economic sectors, markets and investment instruments. Risk and quality are viewed in the context of the diversification requirements of the aggregate portfolio. We measure and monitor investment risk on an ongoing basis through quarterly investment portfolio reviews, annual liability measurements and periodic asset/liability studies. We do not have a concentration of assets in a single entity, industry, country, commodity or class of investment fund.
	The qualified pension plan maintains a 45% target allocation to fixed income securities, including U.S. treasuries, corporate bonds, high yield bonds, asset-backed securities and derivatives. The derivatives in the fixed income portfolio are fully collateralized. The investment guidelines limit liabilities created with derivatives in the fixed income portfolio to cash equivalents plus 10% of the portfolio's market value. The aggregate risk exposure of the plan can be no greater than that which could be achieved without using derivatives. The qualified pension plan maintains a 35% target allocation to equities, including exposure to large cap growth, large cap value and small cap domestic equity securities, as well as exposure to international equity. There is a 5% target allocation to real estate in a diversified global real estate investment trust (REIT) fund. The remaining 15% target allocation is for investments in other types of funds, including commodities, hedge funds and private equity funds that follow several diversified strategies.
	Employees hired or rehired after December 31, 2007 cannot participate in the qualified pension plan but are participants in the Money Purchase Pension (MPP) plan, a defined contribution pension plan that allows the employee to direct the investments and assume the risk of investment returns. A defined contribution plan specifies the amount of the employer's annual contribution to individual participant accounts established for the retirement benefit. Eligible employees who have completed 30 days of continuous service and have attained age 18 are eligible to participate. Under the MPP plan, we annually deposit a percentage of each participant's pay into an account of the MPP plan. This contribution equals 4% of the participant's compensation plus an additional 4% of compensation above the social security wage base up to the Internal Revenue Service (IRS) compensation limit. The participant is vested in this plan after three years of service. During the year ended October 31, 2013, we contributed $.7 million to the MPP plan.
	OPEB Plan
	We provide certain postretirement health care and life insurance benefits to eligible retirees. The liability associated with such benefits is funded in irrevocable trust funds that can only be used to pay the benefits. Employees are first eligible to retire and receive these benefits at age 55 with ten or more years of service after the age of 45. Employees who met this requirement in 1993 or who retired prior to 1993 are in a “grandfathered” group for whom we pay the full cost of the retiree's coverage. Retirees not in the grandfathered group have a portion of the cost of retiree coverage paid by us, subject to certain annual contribution limits. Retirees are responsible for the full cost of dependent coverage. Effective January 1, 2008, new employees have to complete ten years of service after age 50 to be eligible for benefits, and no benefits are provided to those employees after age 65 when they are automatically eligible for Medicare benefits to cover health costs. Our OPEB plan includes a defined dollar benefit to pay the premiums for Medicare Part D. Employees who meet the eligibility requirements to retire also receive a life insurance benefit. For employees who retire after July 1, 2005, this benefit is $15,000. The life insurance amount for employees who retired prior to this date was calculated as a percentage of their basic life insurance prior to retirement.
	OPEB plan assets are comprised of mutual funds within a 401(h) and Voluntary Employees' Beneficiary Association trusts. The investment philosophy is similar to the qualified pension plan as discussed above. We target an OPEB allocation of 45% to fixed income securities, including U.S. treasuries, corporate bonds, high yield bonds and asset-backed securities. The OPEB plan maintains a 47% target allocation to equities, which includes exposure to large cap growth, large cap value and small cap domestic equity, as well as exposure to international equity. The OPEB plan maintains a 5% target allocation to real estate in a diversified global REIT fund and a 3% target allocation to cash. We do not have a concentration of assets in a single entity, industry, country, commodity or class of investment fund.
	Supplemental Executive Retirement Plans
	We have pension liabilities related to supplemental executive retirement plans (SERPs) for certain former employees, non-employee directors or surviving spouses. There are no assets related to these SERPs, and no additional benefits accrue to the participants. Payments to the participants are made from operating funds during the year. Actuarial information for these nonqualified plans is presented below.
	We have a non-qualified defined contribution restoration plan (DCR plan) for all officers at the vice president level and above where benefits payable under the plan are informally funded annually through a rabbi trust with a bank as the trustee. We contribute 13% of the total cash compensation (base salary, short-term incentive and MVP incentive) that exceeds the IRS compensation limit to the DCR plan account of each covered executive. Participants may not contribute to the DCR plan. Vesting under the DCR plan is five-year cliff vesting, including service prior to adoption of the plan on January 1, 2009, of annual company contributions, and prospective five-year cliff vesting for the one-time opening balances of four Vice Presidents to compensate them for the loss of future benefits under this DCR plan as compared with a terminated SERP. Participants in the DCR plan may provide instructions to us for the deemed investment of their plan accounts. Distribution will occur upon separation of service or death of the participant.
	We have a voluntary deferred compensation plan for the benefit of all director-level employees and officers, where we make no contributions to this plan. Benefits under this plan, known as the Voluntary Deferral Plan, are also informally funded monthly through a rabbi trust with a bank as the trustee. Participants may defer up to 50% of base salary with elections made by December 31 prior to the upcoming calendar year, and up to 95% of annual incentive pay with elections made by April 30. Vesting is immediate and deferrals are held in the rabbi trust. Participants may provide instructions to us for the deemed investment of their plan accounts. Distributions can be made from the Voluntary Deferral Plan on a specified date that is at least two years from the date of deferral, on separation of service or upon death.
	The funding to the DCR plan accounts for the years ended October 31, 2013 and 2012, and the amounts recorded as liabilities for these deferred compensation plans as of October 31, 2013 and 2012 are presented below.
	In thousands			2013			2012
	Funding		$	434		$	422
	Liability:
	Current			199			160
	Noncurrent			3,328			2,412
	We provide term life insurance policies for certain officers at the vice president level and above who were former participants in a terminated SERP; the level of the insurance benefit is dependent upon the level of the benefit provided under the terminated SERP. These life insurance policies are owned exclusively by each officer. Premiums on these policies are paid and expensed. We also provide a term life insurance benefit equal to $200,000 to all officers and director-level employees for which we bear the cost of the policies. The cost of these premiums is presented below.
	In thousands		2013			2012			2011
	Term life policies of certain officers at the vice president
	level and above	$	27		$	43		$	56
	Officers and director-level employees		28			25			24
	Actuarial Plan Information
	A reconciliation of changes in the plans' benefit obligations and fair value of assets for the years ended October 31, 2013 and 2012, and a statement of the funded status and the amounts reflected in the Consolidated Balance Sheets for the years ended October 31, 2013 and 2012 are presented below.
		Qualified Pension						Nonqualified Pension					Other Benefits
	In thousands	2013			2012			2013			2012		2013		2012
	Accumulated benefit obligation at year end	$	230,175		$	245,361		$	4,736		$	5,569		N/A		N/A
	Change in projected benefit obligation:
	Obligation at beginning of year	$	293,327		$	236,632		$	5,569		$	5,219	$	34,830	$	31,900
	Service cost		12,005			9,573			-			39		1,327		1,387
	Interest cost		9,946			10,640			157			203		1,130		1,347
	Actuarial (gain) loss		-24,859			54,852			-540			629		-1,094		2,630
	Participant contributions		-			-			-			-		641		788
	Administrative expenses		-534			-420			-			-		-		-
	Benefit payments		-17,482			-17,950			-450			-521		-3,156		-3,222
	Obligation at end of year		272,403			293,327			4,736			5,569		33,678		34,830
	Change in fair value of plan assets:
	Fair value at beginning of year		272,337			259,511			-			-		23,663		22,045
	Actual return on plan assets		26,340			31,196			-			-		2,848		1,972
	Employer contributions		20,000			-			450			521		1,965		2,080
	Participant contributions		-			-			-			-		641		788
	Administrative expenses		-534			-420			-			-		-		-
	Benefit payments		-17,482			-17,950			-450			-521		-3,156		-3,222
	Fair value at end of year		300,661			272,337			-			-		25,961		23,663
	Funded status at year end - (under) over	$	28,258		$	-20,990		$	-4,736		$	-5,569	$	-7,717	$	-11,167
	Noncurrent assets	$	28,258		$	-		$	-		$	-	$	-	$	-
	Current liabilities		-			-			-445			-502		-		-
	Noncurrent liabilities		-			-20,990			-4,291			-5,067		-7,717		-11,167
	Net amount recognized	$	28,258		$	-20,990		$	-4,736		$	-5,569	$	-7,717	$	-11,167
	Amounts Not Yet Recognized as a Component
	of Cost and Recognized in a Deferred
	Regulatory Account:
	Unrecognized transition obligation	$	-		$	-		$	-		$	-	$	-	$	-667
	Unrecognized prior service (cost) credit		17,243			19,441			-196			-277		-		-
	Unrecognized actuarial loss		-96,338			-137,633			-820			-1,521		-354		-2,633
Regulatory asset		-79,095			-118,192			-1,016			-1,798		-354		-3,300
Cumulative employer contributions in
excess of cost		107,353			97,202			-3,720			-3,771		-7,363		-7,867
Net amount recognized	$	28,258		$	-20,990		$	-4,736		$	-5,569	$	-7,717	$	-11,167
In 2006 with the implementation of accounting guidance for employers' accounting for defined benefit pension and other postretirement plans, the NCUC, the PSCSC and the TRA approved our request to place certain defined benefit postretirement obligations in a deferred regulatory account instead of OCIL as presented above. The regulators have allowed future recovery of our pension and OPEB costs to this date.
Net periodic benefit cost for the years ended October 31, 2013, 2012 and 2011 includes the following components.
	Qualified Pension									Nonqualified Pension						Other Benefits
In thousands	2013			2012			2011			2013		2012		2011		2013		2012		2011
Service cost	$	12,005		$	9,573		$	8,508		$	-	$	39	$	45	$	1,327	$	1,387	$	1,398
Interest cost		9,946			10,640			11,024			157		203		209		1,130		1,347		1,495
Expected return on plan
assets		-21,105			-20,289			-20,608			-		-		-		-1,663		-1,551		-1,534
Amortization of transition
obligation		-			-			-			-		-		-		667		667		667
Amortization of prior
service cost (credit)		-2,198			-2,198			-2,198			81		81		20		-		-		-
Amortization of net loss		11,202			5,966			3,547			161		49		41		-		-		-
Net periodic benefit cost		9,850			3,692			273			399		372		315		1,461		1,850		2,026
Other changes in plan
assets and benefit
obligation recognized
through regulatory asset
or liability:
Prior service cost		-			-			-			-		-		290		-		-		-
Net loss (gain)		-30,094			43,945			17,539			-540		629		130		-2,278		2,209		415
Amounts recognized as a
component of net periodic
benefit cost:
Transition obligation		-			-			-			-		-		-		-667		-667		-667
Amortization of net loss		-11,202			-5,966			-3,547			-161		-49		-41		-		-		-
Prior service (cost) credit		2,198			2,198			2,198			-81		-81		-20		-		-		-
Total recognized in
regulatory asset (liability)		-39,098			40,177			16,190			-782		499		359		-2,945		1,542		-252
Total recognized in net
periodic benefit cost and
regulatory asset (liability)	$	-29,248		$	43,869		$	16,463		$	-383	$	871	$	674	$	-1,484	$	3,392	$	1,774
The 2014 estimated amortization of the following items for our plans, which are recorded as a regulatory asset or liability instead of accumulated OCIL discussed above, are as follows.
In thousands	Qualified Pension			Nonqualified Pension			Other Benefits
Amortization of unrecognized prior service cost (credit)	$	-2,198		$	81		$	-
Amortization of unrecognized actuarial loss		7,138			47			-
The discount rate has been separately determined for each plan by projecting the plan's cash flows and developing a zero-coupon spot rate yield curve using non-arbitrage pricing and non-callable bonds rated AA or better by either Moody's Investors Service's or Standard & Poor's Ratings Services that have a yield higher than the regression mean yield curve. The discount rate can vary from plan year to plan year. As of October 31, 2013, the benchmark by plan was as follows.
Pension plan		4.55%
NCNG SERP		3.89%
Directors' SERP		4.09%
Piedmont SERP		3.31%
OPEB		4.44%
Equity market performance has a significant effect on our market-related value of plan assets. In determining the market-related value of plan assets, we use the following methodology: The asset gain or loss is determined each year by comparing the fund's actual return to the expected return, based on the disclosed expected return on investment assumption. Such asset gain or loss is then recognized ratably over a five-year period. Thus, the market-related value of assets as of year end is determined by adjusting the market value of assets by the portion of the prior five years' gains or losses that has not yet been recognized, meaning that 20% of the prior five years' asset gains and losses are recognized each year. This method has been applied consistently in all years presented in the consolidated financial statements.
We amortize unrecognized prior-service cost over the average remaining service period for active employees. We amortize the unrecognized transition obligation over the average remaining service period for active employees expected to receive benefits under the plan as of the date of transition. We amortize gains and losses in excess of 10% of the greater of the benefit obligation and the market-related value of assets over the average remaining service period for active employees. The amortization period used for the purposes mentioned above for the NCNG SERP and the Piedmont SERP is an expected future lifetime as there are no active members in these plans. The method of amortization in all cases is straight-line.
The weighted average assumptions used in the measurement of the benefit obligation as of October 31, 2013 and 2012 are presented below.
	Qualified Pension		Nonqualified Pension		Other Benefits
	2013	2012	2013	2012	2013	2012
Discount rate	4.55%	3.51%	3.98%	2.95%	4.44%	3.34%
Rate of compensation increase	3.72%	3.76%	N/A	N/A	N/A	N/A
The weighted average assumptions used to determine the net periodic benefit cost as of October 31, 2013, 2012 and 2011 are presented below.
	Qualified Pension			Nonqualified Pension
	2013	2012	2011	2013	2012	2011
Discount rate	3.51%	4.67%	5.47%	2.95%	4.10%	4.37%
Expected long-term rate of return on plan assets	8.00%	8.00%	8.00%	N/A	N/A	N/A
Rate of compensation increase	3.76%	3.78%	3.87%	N/A	N/A	N/A
	Other Benefits
	2013	2012	2011
Discount rate	3.34%	4.36%	4.85%
Expected long-term rate of return on plan assets	8.00%	8.00%	8.00%
Rate of compensation increase	N/A	N/A	N/A
We anticipate that we will contribute the following amounts to our plans in 2014.
In thousands
Qualified pension plan *	$	20,000
Nonqualified pension plans		444
MPP plan		885
OPEB plan		1,500
* Funded in November 2013.
The Pension Protection Act of 2006 (PPA) specified funding requirements for single employer defined benefit pension plans. The PPA established a 100% funding target for plan years beginning after December 31, 2007, and we are in compliance.
Benefit payments, which reflect expected future service, as appropriate, are expected to be paid for the next ten years ending October 31 as follows.
	Qualified			Nonqualified			Other
In thousands	Pension			Pension			Benefits
2014	$	25,918		$	444		$	2,140
2015		16,918			458			2,262
2016		15,169			434			2,322
2017		16,154			410			2,417
2018		18,672			383			2,507
2019 - 2023		106,226			1,890			13,640
The assumed health care cost trend rates used in measuring the accumulated OPEB obligation for the medical plans for all participants as of October 31, 2013 and 2012 are presented below.
	2013		2012
Health care cost trend rate assumed for next year	7.40%		7.50%
Rate to which the cost trend is assumed to decline (the ultimate trend rate)	5.00%		5.00%
Year that the rate reaches the ultimate trend rate	2027		2027
The health care cost trend rate assumptions could have a significant effect on the amounts reported. A change of 1% would have the following effects.
In thousands			1% Increase			1% Decrease
Effect on total of service and interest cost components of net periodic
postretirement health care benefit cost for the year ended October 31, 2013			$	21		$	-27
Effect on the health care cost component of the accumulated postretirement
benefit obligation as of October 31, 2013				690			-699
Fair Value Measurements
Mutual funds are valued at the quoted NAV per share, which is computed as of the close of business on our balance sheet date. Mutual funds with a publicly quoted NAV per share are classified as Level 1; mutual funds with a NAV per share that is not publicly available are classified as Level 2.
Following is a description of the valuation methodologies used for assets measured at fair value in our qualified pension plan.
Cash and cash equivalents – These are Level 1 assets valued at face value as they are primarily cash       or cash equivalents. The assets that are Level 2 assets have been valued at the market value of the shares held by the plan at the valuation date for a money market mutual fund.
U.S. treasuries – These are Level 2 assets whose values are based on observable market information including quotes from a quotation reporting system, established market makers or pricing services. This asset class includes long duration fixed income investments.
Long duration bonds – These are Level 2 assets in an actively managed private series long duration fixed income fund valued using pricing models that consider various observable inputs, such as benchmark yields, reported trades, broker quotes and issuer spreads.
Corporate bonds, collateralized mortgage obligations, municipals – These are Level 2 assets valued based on primarily observable market information or broker quotes on a non-active market. This class includes long duration fixed income investments.
High yield bonds – These are Level 1 assets valued at the quoted NAV of high yield fixed income mutual fund shares.
Derivatives – The Level 1 assets were valued using a compilation of observable market information on an active market. The Level 2 assets were valued using broker quotes on a non-active market.
Large cap core index – These are Level 1 assets valued at the quoted NAV of the low-cost equity index mutual fund that tracks the Standard & Poor's 500 Stock Index (S&P 500 Index).
Large cap value and small cap value – These are Level 1 assets valued at the market price of the active market on which the individual security is traded.
Large cap growth and global REIT (and for 2012, international value) – These are Level 1 assets valued at the quoted NAV of mutual fund shares in managed equity funds.
Common trust funds – International growth and international value – These are Level 2 assets held in common trust funds in which we own interests that are valued at the NAV of the funds as traded on international exchanges. Currently there are no restrictions on redemptions for the funds.
Hedge fund of funds – This is a Level 2 asset with the value of our investment based on the estimated fair value of the underlying holdings in the portfolio at a NAV. These investments are across a variety of markets through investment funds or managed accounts that invest in equities, equity-related instruments, fixed income and other debt-related instruments. Currently there are no restrictions on redemptions for the fund.
Private equity fund of funds – This is a Level 3 asset invested in hedge fund of funds valued based on a quarterly compilation of the financial statements from the underlying partnerships in which the fund invests. There are currently redemption restrictions for this fund. The target allocation for this investment is 5% but is still being funded through capital calls; $7.4 million of the original $12 million subscription remains unfunded. Until a 5% allocation can be achieved, the balance of the 5% allocation is invested in a low-cost equity index fund that tracks the S&P 500 Index. Our investment is in various funds that invests in North American companies; allocate capital to private equity funds; invest in venture capital partnerships; and private equity partnerships in emerging markets.
Commodities fund of funds – This is a Level 2 asset with the value of our investment based on the estimated fair value of the various holdings in the portfolio as reported in the financial statements at a NAV. Currently there are no restrictions on redemptions for the fund. These investments are in commodities fund of funds that are actively managed through a well-diversified group of underlying managers.
As stated above, some of our investments for the qualified pension plan have redemption limitations, restrictions and notice requirements which are further explained below.
						Redemptions
		Redemption				Notice
Investment		Frequency		Other Redemption Restrictions		Period
Common trust fund -		Monthly		None		30 days
International growth
Common trust fund -		Daily		None		5 days
International value
Hedge fund of funds		Quarterly		Redeemed in whole or part but not less than the minimum redemption amount for each currency. Redemption within one year of purchase is subject to 1.5% redemption fee. Redeemed on "first in first out" basis. None of our investment is subject to the redemption fee. Fund's Board of Directors may limit or suspend share redemptions until a further notification ending suspension. No such notification has been received as of October 31, 2013.		65 days
Private equity fund of funds		Limited		Investors have only very limited withdrawal rights for specific legal or regulatory reasons. Any transfer of interest will be subject to approval.		-1
Commodities fund of funds		Monthly		Redemption within one year of purchase is subject to 1% redemption fee. None of our investment is subject to the redemption fee. If 95% or more of the balance is requested, 95% of the balance will be paid within 30 days. Any outstanding balance or interest owed will be paid after the annual audit is complete.		35 days
(1) The investment cannot be redeemed. We receive distributions only through the liquidation of the underlying assets. The assets are expected to be liquidated over the next 10 to 12 years.
The qualified pension plan's asset allocations by level within the fair value hierarchy at October 31, 2013 and 2012 are presented below. Our assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the valuation of fair value assets and their consideration within the fair value hierarchy levels. For further information on a description of the fair value hierarchy, see “Fair Value Measurements” in Note 1 to the consolidated financial statements.
	Qualified Pension Plan as of October 31, 2013
				Significant
	Quoted Prices			Other			Significant
	in Active			Observable			Unobservable			Total
	Markets			Inputs			Inputs			Carrying		% of
In thousands	(Level 1)			(Level 2)			(Level 3)			Value		Total
Cash and cash equivalents	$	5,566		$	156		$	-		$	5,722	2%
Fixed Income Securities:												38%
U.S. treasuries		-			24,078			-			24,078	8%
Long duration bonds		-			34,041			-			34,041	11%
Corporate bonds		-			42,701			-			42,701	14%
High yield bonds		14,680			-			-			14,680	5%
Collateralized mortgage
obligations		-			1,098			-			1,098	-%
Municipals		-			-			-			-	-%
Derivatives		6			-17			-			-11	-%
Equity Securities:												43%
Large cap core index		12,023			-			-			12,023	4%
Large cap value		16,908			-			-			16,908	6%
Large cap growth		17,823			-			-			17,823	6%
Small cap value		30,831			-			-			30,831	10%
Common trust fund - International
value		-			24,460			-			24,460	8%
Common trust fund - International
growth		-			27,270			-			27,270	9%
Real Estate:												5%
Global REIT		15,042			-			-			15,042	5%
Other Investments:												12%
Hedge fund of funds		-			18,571			-			18,571	6%
Private equity fund of funds		-			-			4,659			4,659	2%
Commodities fund of funds		-			10,765			-			10,765	4%
Total assets at fair value	$	112,879		$	183,123		$	4,659		$	300,661	100%
Percent of fair value hierarchy		37%			61%			2%			100%
	Qualified Pension Plan as of October 31, 2012
					Significant
		Quoted Prices			Other			Significant
		in Active			Observable			Unobservable			Total
		Markets			Inputs			Inputs			Carrying	% of
In thousands		(Level 1)			(Level 2)			(Level 3)			Value	Total
Cash and cash equivalents	$	5,346		$	-		$	-		$	5,346	2%
Fixed Income Securities:												45%
U.S. treasuries		-			17,544			-			17,544	6%
Long duration bonds		-			63,565			-			63,565	23%
Corporate bonds		-			26,368			-			26,368	10%
High yield bonds		13,777			-			-			13,777	5%
Collateralized mortgage
obligations		-			1,513			-			1,513	1%
Municipals		-			345			-			345	-%
Derivatives		-3			-86			-			-89	-%
Equity Securities:												36%
Large cap core index		10,260			-			-			10,260	4%
Large cap value		10,427			-			-			10,427	4%
Large cap growth		15,252			-			-			15,252	6%
Small cap value		26,335			-			-			26,335	10%
International value		14,376			-			-			14,376	5%
Common trust fund - International
growth		-			18,678			-			18,678	7%
Real Estate:												6%
Global REIT		16,252			-			-			16,252	6%
Other Investments:												11%
Hedge fund of funds		-			16,995			-			16,995	6%
Private equity fund of funds		-			-			3,522			3,522	1%
Commodities fund of funds		-			11,871			-			11,871	4%
Total assets at fair value	$	112,022		$	156,793		$	3,522		$	272,337	100%
Percent of fair value hierarchy		41%			58%			1%			100%
In 2012, we transferred amounts from Level 3 to Level 2 for our investments in the hedge fund of funds and the commodities fund of funds because inputs became more observable. The international value fund that was classified as a Level 1 asset as of October 31, 2012 was sold, and the proceeds were invested in the common trust fund – international value during fiscal year 2013. The following is a reconciliation of the assets in the qualified pension plan that are classified as Level 3 in the fair value hierarchy.
				Private
	Hedge Fund			Equity Fund			Commodities
In thousands	of Funds			of Funds			Fund of Funds				Total
Balance, October 31, 2011	$	6,207		$	1,925		$	8,472		$	16,604
Actual return on plan assets:
Relating to assets still held at the reporting date		-			13			-			13
Relating to assets sold during the period		-			145			-			145
Purchases, sales and settlements (net)		-			1,439			-			1,439
Transfer in/out of Level 3		-6,207			-			-8,472			-14,679
Balance, October 31, 2012		-			3,522			-			3,522
Actual return on plan assets:
Relating to assets still held at the reporting date		-			116			-			116
Relating to assets sold during the period		-			61			-			61
Purchases, sales and settlements (net)		-			960			-			960
Transfer in/out of Level 3		-			-			-			-
Balance, October 31, 2013	$	-		$	4,659		$	-		$	4,659
During the year, the qualified pension plan raises cash from various plan assets in order to fund periodic and lump sum benefit payments. Cash is raised as needed primarily from investments that have exceeded their target allocation and is dependent upon the number of retirees seeking lump sum distributions.
There are significant unobservable inputs used in the fair value measurements of our investment in the private equity fund of funds' limited partnerships. We are subject to the business risks inherent in the markets in which the partnerships are invested. The success or failure of the underlying businesses of the various partnerships that have been funded would result in a higher or lower fair value measurement.
Following is a description of the valuation methodologies used for assets measured at fair value in our OPEB plan with all of the OPEB plan's assets invested in mutual funds.
Cash and cash equivalents – These are Level 1 assets having maturities of three months or less when purchased and are considered to be cash equivalents.
U.S. treasuries – These are Level 1 assets in an actively managed mutual fund measured at NAV.
Corporate bonds/Other fixed income securities – These are Level 1 assets valued at the quoted NAV of mutual fund investments that are primarily invested in investment grade securities that mature within ten years. The OPEB plan maintains a 5% target allocation to a high yield bond fund.
Large cap value, large cap growth, small cap growth, small cap value – These are Level 1 assets valued at the quoted NAV as invested in mutual funds that invest by a specific style.
Large cap index – These are Level 1 assets valued at the NAV as invested in a low-cost equity index mutual fund that tracks the S&P 500 Index.
International blend – These are Level 1 assets valued at the quoted NAV of mutual fund shares in managed global equity funds outside of the United States whose styles include both growth and value investments.
Global REIT – These are Level 1 assets valued at the quoted NAV of mutual fund shares in a managed equity fund that invests globally but primarily in the United States.
The OPEB plan's asset allocations by level within the fair value hierarchy at October 31, 2013 and 2012 are presented below. Our assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the valuation of fair value assets and their placement within the fair value hierarchy levels. For further information on a description of the fair value hierarchy, see “Fair Value Measurements” in Note 1 to the consolidated financial statements.
	Other Benefits as of October 31, 2013
				Significant
	Quoted Prices			Other			Significant
	in Active			Observable			Unobservable			Total
	Markets			Inputs			Inputs			Carrying		% of
In thousands	(Level 1)			(Level 2)			(Level 3)			Value		Total
Cash and cash equivalents	$	982		$	-		$	-		$	982	4%
Fixed Income Securities:												46%
U.S. treasuries		2,582			-			-			2,582	10%
Corporate bonds / Other fixed
income securities		9,232			-			-			9,232	36%
Equity Securities:												45%
Large cap value		1,327			-			-			1,327	5%
Large cap growth		1,352			-			-			1,352	5%
Small cap value		1,331			-			-			1,331	5%
Small cap growth		1,313			-			-			1,313	5%
Large cap index		2,384			-			-			2,384	9%
International blend		4,206			-			-			4,206	16%
Real Estate:												5%
Global REIT		1,252			-			-			1,252	5%
Total assets at fair value	$	25,961		$	-		$	-		$	25,961	100%
Percent of fair value hierarchy		100%			-%			-%			100%
	Other Benefits as of October 31, 2012
				Significant
	Quoted Prices			Other			Significant
	in Active			Observable			Unobservable			Total
	Markets			Inputs			Inputs			Carrying		% of
In thousands	(Level 1)			(Level 2)			(Level 3)			Value		Total
Cash and cash equivalents	$	926		$	-		$	-		$	926	4%
Fixed Income Securities:												46%
U.S. treasuries		2,345			-			-			2,345	10%
Corporate bonds / Other fixed
income securities		8,474			-			-			8,474	36%
Equity Securities:												45%
Large cap value		1,221			-			-			1,221	5%
Large cap growth		1,149			-			-			1,149	5%
Small cap value		1,177			-			-			1,177	5%
Small cap growth		1,155			-			-			1,155	5%
Large cap index		2,148			-			-			2,148	9%
International blend		3,907			-			-			3,907	16%
Real Estate:												5%
Global REIT		1,161			-			-			1,161	5%
Total assets at fair value	$	23,663		$	-		$	-		$	23,663	100%
Percent of fair value hierarchy		100%			-%			-%			100%
401(k) Plan
We maintain a 401(k) plan that is a profit-sharing plan under Section 401(a) of the Internal Revenue Code of 1986, as amended (the Tax Code), which includes qualified cash or deferred arrangements under Tax Code Section 401(k). The 401(k) plan is subject to the provisions of the Employee Retirement Income Security Act. Eligible employees who have completed 30 days of continuous service and have attained age 18 are eligible to participate. Participants may defer a portion of their base salary and cash incentive payments to the plan, and we match a portion of their contributions. Employee contributions vest immediately, and company contributions vest after six months of service.
Employees receive a company match of 100% up to the first 5% of eligible pay contributed. Employees may contribute up to 50% of eligible pay to the 401(k) on a pre-tax basis, up to the Tax Code annual contribution and compensation limits. We automatically enroll all eligible non-participating employees in the 401(k) plan at a 2% contribution rate unless the employee chooses not to participate by notifying our record keeper. For employees who are automatically enrolled in the 401(k) plan, we automatically increase their contributions by 1% each year to a maximum of 5% unless the employee chooses to opt out of the automatic increase by contacting our record keeper. If the employee does not make an investment election, employee contributions and matches are automatically invested in a diversified portfolio of stocks and bonds. Participants may direct up to 20% of their contributions and company matching contributions as an investment in the Piedmont Stock Fund. Employees may change their contribution rate and investments at any time. For the years ended October 31, 2013, 2012 and 2011, we made matching contributions to participant accounts as follows.
In thousands		2013			2012			2011
401(k) matching contributions		$	5,688		$	5,400		$	5,203
As a result of a plan merger effective in 2001, participants' accounts in our employee stock ownership plan (ESOP) were transferred into the participants' 401(k) accounts. Former ESOP participants may remain invested in Piedmont common stock in their 401(k) plan or may sell the common stock at any time and reinvest the proceeds in other available investment options. The tax benefit of any dividends paid on ESOP shares still in participants' accounts is reflected in the Consolidated Statement of Stockholders' Equity as an increase in retained earnings.

Employee_Share_Based_Plans

Employee Share Based Plans	12 Months Ended
	Oct. 31, 2013
Employee Share Based Plans Details [Abstract]	'
Disclosure Of Compensation Related Costs Share Based Payments Text Block	'
	10. Employee Share-Based Plans
	Under our shareholder approved ICP, eligible officers and other participants are awarded units that pay out depending upon the level of performance achieved by Piedmont during three-year incentive plan performance periods. Distribution of those awards may be made in the form of shares of common stock and withholdings for payment of applicable taxes on the compensation. These plans require that a minimum threshold performance level be achieved in order for any award to be distributed. For the years ended October 31, 2013, 2012 and 2011, we recorded compensation expense, and as of October 31, 2013 and 2012, we accrued a liability for these awards based on the fair market value of our stock at the end of each quarter. The liability is re-measured to market value at the settlement date.
	We have granted three series of awards under approved incentive compensation plans, each with a three-year performance period (ending October 31, 2013, October 31, 2014 and October 31, 2015). For each of these performance periods, awards will be based on achievement relative to a target annual compounded increase in basic EPS and the achievement of total shareholder returns relative to a group of peer companies that are domiciled in the United States, publicly traded in the U.S. energy industry with a primary focus on natural gas distribution and transmission businesses in multi-state territories and have similar annual revenues and market capitalization to ours, with each measure being weighted at 50%. The plan with the performance period ending October 31, 2015 (2015 plan) has an additional performance measure of actual average return on equity compared to the weighted average return on equity allowed by our regulatory commissions. The weighting of the units awarded under the 2015 plan is based on EPS at 37.5%, total shareholder return at 37.5 % and return on equity at 25% of the total units awarded.
	In December 2010, a long-term retention stock unit award under the ICP (where a stock unit equals one share of our common stock upon vesting) was approved for eligible officers and other participants to support our succession planning and retention strategies. This retention stock unit award will vest for participants who have met the retention requirements at the end of a three-year period ending in December 2013 in the form of shares of common stock and withholdings for payment of applicable taxes on the compensation. The Compensation Committee of our Board of Directors has the discretion to accelerate the vesting of all or a portion of a participant's units. For the twelve months ended October 31, 2013, 2012 and 2011, we recorded compensation expense, and as of October 31, 2013 and 2012, we accrued a liability for these awards based on the fair market value of our stock at the end of each quarter. The liability is re-measured to market value at the settlement date.
	Also under our approved ICP, 64,700 unvested retention stock units were granted to our President and Chief Executive Officer in December 2011. During the five-year vesting period, any dividend equivalents will accrue on these stock units and be converted into additional units at the same rate and based on the closing price on the same payment date as dividends on our common stock. The stock units will vest, payable in the form of shares of common stock and withholdings for payment of applicable taxes on the compensation, over a five-year period only if he is an employee on each vesting date. In accordance with the vesting schedule, 20% of the units vest on December 15, 2014, 30% of the units vest on December 15, 2015 and 50% of the units vest on December 15, 2016. For the twelve months ended October 31, 2013 and 2012, we recorded compensation expense, and as of October 31, 2013 and 2012, we accrued a liability for this award based on the fair market value of our stock at the end of each quarter. The liability is re-measured to market value at the settlement date.
	At the time of distribution of awards under the ICP, the number of shares issuable is reduced by the withholdings for payment of applicable income taxes for each participant. The participant may elect income tax withholdings at or above the minimum statutory withholding requirements. The maximum withholdings allowed is 50%. To date, shares withheld for payment of applicable income taxes have been immaterial. We present these net shares issued in the Consolidated Statements of Stockholders' Equity.
	The compensation expense related to the incentive compensation plans for the years ended October 31, 2013, 2012 and 2011, and the amounts recorded as liabilities as of October 31, 2013 and 2012 are presented below.
	In thousands		2013		2012		2011
	Compensation expense	$	4,526	$	5,730	$	2,604
	Tax benefit		1,538		2,080		673
	Liability		11,098		10,631
	Based on current accrual assumptions as of October 31, 2013, the expected payout for the approved incentive compensation awards at target will occur in the following fiscal years.
	In thousands	2014		2015		2016		2017
	Amount of payout	$	4,071	$	4,290	$	2,290	$	446
	On a quarterly basis, we issue shares of common stock under the ESPP and account for the issuance as an equity transaction. The exercise price is calculated as 95% of the fair market value on the purchase date of each quarter where fair market value is determined by calculating the mean average of the high and low trading prices on the purchase date.

Income_Taxes

Income Taxes	12 Months Ended
	Oct. 31, 2013
Income Taxes Disclosure [Abstract]	'
Income Tax Disclosure Text Block	'
	11. Income Taxes
	The components of income tax expense for the years ended October 31, 2013, 2012 and 2011 are presented below.
			2013						2012				2011
	In thousands		Federal			State			Federal		State		Federal		State
	Charged (Credited) to operating income:
	Current		$	-3,032		$	919		$	-29,062	$	1,857	$	-11,403	$	4,209
	Deferred			67,885			11,829			86,496		10,144		64,806		6,597
	Tax Credits:
	Utilization			-			-			-		-		184		-
	Amortization			-267			-			-334		-		-325		-
	Total			64,586			12,748			57,100		12,001		53,262		10,806
	Charged (Credited) to other income (expense):
	Current			6,049			984			5,636		1,027		3,263		-36
	Deferred			2,225			-646			2,214		239		4,167		824
	Total			8,274			338			7,850		1,266		7,430		788
	Total		$	72,860		$	13,086		$	64,950	$	13,267	$	60,692	$	11,594
	A reconciliation of income tax expense at the federal statutory rate to recorded income tax expense for the years ended October 31, 2013, 2012 and 2011 is presented below.
	In thousands		2013			2012			2011
	Federal taxes at 35%		$	77,127		$	69,322		$	65,049
	State income taxes, net of federal benefit			8,506			8,624			7,536
	Amortization of investment tax credits			-267			-334			-325
	Other, net			580			605			26
	Total		$	85,946		$	78,217		$	72,286
	As of October 31, 2013 and 2012, deferred income taxes consisted of the following temporary differences.
	In thousands		2013			2012
	Deferred tax assets:
	Benefit of loss carryforwards	$	66,087		$	3,092
	Employee benefits and compensation		13,834			22,286
	Revenue requirement		19,062			10,148
	Utility plant		10,386			11,285
	Other		12,796			9,173
	Total deferred tax assets		122,165			55,984
	Valuation allowance		-505			-505
	Total deferred tax assets, net		121,660			55,479
	Deferred tax liabilities:
	Utility plant		652,822			523,232
	Revenues and cost of gas		21,257			26,816
	Equity method investments		38,710			34,092
	Deferred costs		59,221			73,744
	Other		18,324			8,348
	Total deferred tax liabilities		790,334			666,232
	Net deferred income tax liabilities	$	668,674		$	610,753
	As of October 31, 2013 and 2012, total net deferred income tax assets were net of a valuation allowance to reduce amounts to the amounts that we believe will be more likely than not realized. We and our wholly owned subsidiaries file a consolidated federal income tax return and various state income tax returns. As of October 31, 2013, we have a federal NOL carryforward of $178.1 million, which expires in 2033. We also have $5.9 million of federal NOL carryforwards as of October 31, 2013 and 2012 that expire in 2021 through 2025 and are subject to an annual limitation of $.3 million.
	As of October 31, 2013 and 2012, we have state NOL carryforwards of $6.4 million and $6.8 million, respectively, that expire from 2020 through 2028. We may use the carryforwards to offset taxable income.
	We have federal charitable contribution carryforwards as of October 31, 2013 and 2012 of $4.2 million and $2.3 million, respectively, that expire from 2016 through 2018.
	We are no longer subject to federal income tax examinations for tax years ending before and including October 31, 2009, and with few exceptions, state income tax examinations by tax authorities for years ended before and including October 31, 2009.
	A reconciliation of changes in the deferred tax valuation allowance for the years ended October 31, 2013, 2012 and 2011 is presented below.
	In thousands		2013			2012			2011
	Balance at beginning of year	$	505		$	505		$	1,324
	Credited to income tax expense		-			-			-819
	Balance at end of year	$	505		$	505		$	505
	There were no unrecognized tax benefits for the years ended October 31, 2013 and 2012.
	In July 2013, legislation was passed in North Carolina affecting corporate taxation. The legislation reduces the corporate income tax rate from 6.9% to 6% for tax years beginning after January 1, 2014 and to 5% for tax years beginning after January 1, 2015. It also provides for two additional 1% rate reductions if the state's tax collections exceed certain thresholds. We record deferred income taxes on temporary tax differences using the income tax rate in effect when the temporary difference is expected to reverse. As a result of the rate reductions, we adjusted our noncurrent deferred income tax balances at October 31, 2013 by approximately $25 million for temporary differences expected to reverse at a lower rate than under the prior law and recognized a tax benefit of approximately $1 million in net income, the majority of which relates to our non-utility activities segment, with the balance of approximately $24 million recorded in deferred income taxes in “Regulatory Liabilities” in Note 1 to the consolidated financial statements, reflecting a future benefit to our customers; our state commissions will determine the recovery period of this regulatory liability in future proceedings.

Equity_Method_Investments

Equity Method Investments	12 Months Ended
	Oct. 31, 2013
Equity Method Investments Disclosure [Abstract]	'
Equity Method Investments Disclosure Text Block	'
	12. Equity Method Investments
	The consolidated financial statements include the accounts of wholly owned subsidiaries whose investments in joint venture, energy-related businesses are accounted for under the equity method. Our ownership interest in each entity is included in “Equity method investments in non-utility activities” in “Noncurrent Assets” in the Consolidated Balance Sheets. Earnings or losses from equity method investments are included in “Income from equity method investments” in “Other Income (Expense)” in the Consolidated Statements of Comprehensive Income.
	As of October 31, 2013, there were no amounts that represented undistributed earnings of our 50% or less owned equity method investments in our retained earnings.
	Cardinal Pipeline Company, L.L.C.
	We own 21.49% of the membership interests in Cardinal Pipeline Company, L.L.C. (Cardinal), a North Carolina limited liability company. The other members are subsidiaries of The Williams Companies, Inc., and SCANA Corporation. Cardinal owns and operates an intrastate natural gas pipeline in North Carolina and is regulated by the NCUC. Cardinal has firm, long-term service agreements with local distribution companies for 100% of the firm transportation capacity on the pipeline, of which Piedmont subscribes to approximately 53%. Cardinal is dependent on the Williams – Transco pipeline system to deliver gas into its system for service to its customers.
	To provide natural gas delivery service to Duke Energy Progress, Inc. (DEP), now a subsidiary of DEC, for a power generation facility at their Wayne County, North Carolina site, we executed an agreement with Cardinal, which was approved by the NCUC in May 2010, to expand our firm capacity requirement on Cardinal to serve DEP. Cardinal invested in a compressor station and expanded meter stations in order to increase the capacity of its system for us and another customer. We made capital contributions totaling $9.8 million related to this system expansion from January 2011 through June 2012. Cardinal's expansion service for the project and our natural gas delivery service for DEP's Wayne County site were placed into service on June 1, 2012.
	The charges we incur as transportation costs from Cardinal are passed through to DEP under the terms of our natural gas delivery service agreement with DEP. Cardinal issued $45 million of long-term debt on June 22, 2012, and we received a distribution of $5.4 million in June 2012 as a partial return of our capital contributions.
	Cardinal enters into interest-rate swap agreements to modify the interest expense characteristics of its unsecured long-term debt. Our share of movements in the market value of these agreements are recorded as a hedge in “Accumulated other comprehensive loss” in “Stockholders' equity” in the Consolidated Balance Sheets; the detail of our share of the market value of the swap agreements is combined with our other equity method investments and presented in “Other Comprehensive Income (Loss), net of tax” in the Consolidated Statements of Comprehensive Income. Cardinal's long-term debt is nonrecourse to the members.
	We have related party transactions as a transportation customer of Cardinal, and we record the transportation costs charged by Cardinal in “Cost of Gas” in the Consolidated Statements of Comprehensive Income. For each of the years ended October 31, 2013, 2012 and 2011, these transportation costs and the amounts we owed Cardinal as of October 31, 2013 and 2012 are as follows.
	In thousands	2013			2012		2011
	Transportation costs	$	8,775		$	6,613	$	4,104
	Trade accounts payable		755			855
	Summarized financial information provided to us by Cardinal for 100% of Cardinal as of September 30, 2013 and 2012, and for the twelve months ended September 30, 2013, 2012 and 2011 is presented below.
	In thousands	2013			2012		2011
	Current assets	$	15,179		$	9,179
	Noncurrent assets		116,414			120,437
	Current liabilities		2,637			1,786
	Noncurrent liabilities		45,273			45,702
	Revenues		17,649			16,165	$	13,633
	Gross profit		17,649			16,165		13,633
	Income before income taxes		9,361			10,433		6,473
	Pine Needle LNG Company, L.L.C.
	Pine Needle LNG Company, L.L.C. (Pine Needle), a North Carolina limited liability company, owns an interstate LNG storage facility in North Carolina and is regulated by the FERC. Pine Needle has firm, long-term service agreements for 100% of the storage capacity of the facility, of which Piedmont subscribes to approximately 64%. In June 2013, we entered into an agreement with Hess Corporation (Hess) to acquire their 5% membership interest in Pine Needle. Effective July 1, 2013, we acquired Hess' 5% membership interest for $2.9 million. With the purchase of this additional 5% membership interest, our membership interest in Pine Needle increased from 40% to 45%. As of October 31, 2013, the other members are the Municipal Gas Authority of Georgia and subsidiaries of The Williams Companies, Inc. and SCANA Corporation.
	Pine Needle enters into interest-rate swap agreements to modify the interest expense characteristics of its long-term debt. Our share of movements in the market value of these agreements are recorded as a hedge in “Accumulated other comprehensive loss” in “Stockholders' equity” in the Consolidated Balance Sheets; the detail of our share of the market value of the swap agreements is combined with our other equity method investments and presented in “Other Comprehensive Income (Loss), net of tax” in the Consolidated Statements of Comprehensive Income. Pine Needle's long-term debt is nonrecourse to the members.
	We have related party transactions as a customer of Pine Needle, and we record the storage costs charged by Pine Needle in “Cost of Gas” in the Consolidated Statements of Comprehensive Income. For the years ended October 31, 2013, 2012 and 2011, these gas storage costs and the amounts we owed Pine Needle as of October 31, 2013 and 2012 are as follows.
	In thousands	2013			2012		2011
	Gas storage costs	$	11,098		$	10,410	$	10,677
	Trade accounts payable		940			914
	Summarized financial information provided to us by Pine Needle for 100% of Pine Needle as of September 30, 2013 and 2012, and for the twelve months ended September 30, 2013, 2012 and 2011 is presented below.
	In thousands	2013			2012		2011
	Current assets	$	9,225		$	11,937
	Noncurrent assets		74,710			77,463
	Current liabilities		3,531			4,278
	Noncurrent liabilities		35,391			35,851
	Revenues		16,810			16,390	$	17,666
	Gross profit		16,810			16,390		17,666
	Income before income taxes		5,804			5,832		5,763
	SouthStar Energy Services LLC
	We own 15% of the membership interests in SouthStar Energy Services LLC (SouthStar), a Delaware limited liability company. The other member is Georgia Natural Gas Company (GNGC), a wholly-owned subsidiary of AGL Resources, Inc. (AGL). SouthStar primarily sells natural gas to residential, commercial and industrial customers in the southeastern United States, including Illinois, Ohio, New York, Maryland, North Carolina, South Carolina and Tennessee, with most of its business being conducted in the unregulated retail gas market in Georgia. We account for our investment in SouthStar using the equity method, as we have board representation with equal voting rights on significant governance matters and policy decisions, and thus, exercise significant influence over the operations of SouthStar.
	In September 2013, GNGC contributed its retail natural gas marketing assets and customer accounts located in Illinois. AGL acquired these retail assets and customers from Nicor Inc. in December 2011 and additional retail natural gas assets and customer accounts in a separate transaction in June 2013. We made an additional $22.5 million capital contribution to SouthStar, maintaining our 15% equity ownership, related to this transaction.
	SouthStar's business is seasonal in nature as variations in weather conditions generally result in greater revenue and earnings during the winter months when weather is colder and natural gas consumption is higher. Also, because SouthStar is not a rate-regulated company, the timing of its earnings can be affected by changes in the wholesale price of natural gas. While SouthStar uses financial contracts to moderate the effect of price and weather changes on the timing of its earnings, wholesale price and weather volatility can cause variations in the timing of the recognition of earnings.
	These financial contracts, in the form of futures, options and swaps, are considered to be derivatives and fair value is based on selected market indices. Our share of movements in the market value of these contracts are recorded as a hedge in “Accumulated other comprehensive loss” in “Stockholders' equity” in the Consolidated Balance Sheets; the detail of our share of the market value of these contracts is combined with our other equity method investments and presented in “Other Comprehensive Income (Loss), net of tax” in the Consolidated Statements of Comprehensive Income.
	We have related party transactions as we sell wholesale gas supplies to SouthStar, and we record the amounts billed to SouthStar in “Operating Revenues” in the Consolidated Statements of Comprehensive Income. For the years ended October 31, 2013, 2012 and 2011, our operating revenues from these sales and the amounts SouthStar owed us as of October 31, 2013 and 2012 are as follows.
	In thousands	2013			2012		2011
	Operating revenues	$	3,291		$	2,442	$	4,961
	Trade accounts receivable		441			473
	Summarized financial information provided to us by SouthStar for 100% of SouthStar as of September 30, 2013 and 2012, and for the twelve months ended September 30, 2013, 2012 and 2011 is presented below.
	In thousands	2013			2012		2011
	Current assets	$	194,793		$	152,422
	Noncurrent assets		136,753			9,803
	Current liabilities		76,304			42,197
	Noncurrent liabilities		53			1
	Revenues		639,426			585,291	$	733,987
	Gross profit		174,993			161,122		176,010
	Income before income taxes		103,146			94,631		103,704
	Hardy Storage Company, LLC
	We own 50% of the membership interests in Hardy Storage Company, LLC (Hardy Storage), a West Virginia limited liability company. The other owner is a subsidiary of Columbia Gas Transmission Corporation, a subsidiary of NiSource Inc. Hardy Storage owns and operates an underground interstate natural gas storage facility located in Hardy and Hampshire Counties, West Virginia, that is regulated by the FERC. Hardy Storage has firm, long-term service agreements for 100% of the storage capacity of the facility, of which Piedmont subscribes to approximately 40%.
	We have related party transactions as a customer of Hardy Storage, and we record the storage costs charged by Hardy Storage in “Cost of Gas” in the Consolidated Statements of Comprehensive Income. For the years ended October 31, 2013, 2012 and 2011, these gas storage costs and the amounts we owed Hardy Storage as of October 31, 2013 and 2012 are as follows.
	In thousands	2013			2012		2011
	Gas storage costs	$	9,702		$	9,702	$	9,702
	Trade accounts payable		808			808
	Summarized financial information provided to us by Hardy Storage for 100% of Hardy Storage as of October 31, 2013 and 2012, and for the twelve months ended October 31, 2013, 2012 and 2011 is presented below.
	In thousands	2013			2012		2011
Current assets	$	7,641		$	10,302
Noncurrent assets		161,282			164,374
Current liabilities		12,378			14,534
Noncurrent liabilities		87,184			95,061
Revenues		24,375			24,359	$	24,378
Gross profit		24,375			24,359		24,378
Income before income taxes		10,582			9,939		9,657
Constitution Pipeline Company, LLC
We own 24% of the membership interests of Constitution Pipeline Company, LLC (Constitution), a Delaware limited liability company. In May 2013, through one of its subsidiaries, WGL Holdings, Inc. became a member of the joint venture along with existing members The Williams Companies, Inc. and Cabot Oil & Gas Corporation. A subsidiary of The Williams Companies is the operator of the project. The purpose of the joint venture is to construct and operate approximately 120 miles of interstate natural gas pipeline and related facilities connecting shale natural gas supplies and gathering systems in Susquehanna County, Pennsylvania, to the Iroquois Gas Transmission and Tennessee Gas Pipeline systems in New York. We have committed to fund an amount in proportion to our ownership interest for the development and construction of the new pipeline, which is expected to cost approximately $680 million. As of October 31, 2013, our fiscal year contributions were $15.9 million, and we expect our total contributions will be an estimated $55 million and $92.1 million in our fiscal 2014 and 2015 years, respectively. The target in-service date of the project is March 2015. The capacity of the pipeline is 100% subscribed under fifteen year service agreements with two Marcellus producer-shippers with a negotiated rate structure.
Summarized financial information provided to us by Constitution for 100% of Constitution as of September 30, 2013, and for the twelve months ended September 30, 2013 is presented below.
In thousands	2013		-1
Current assets	$	10,944
Noncurrent assets		62,438
Current liabilities		7,960
Noncurrent liabilities		-
Revenues		-
Gross profit		-
Income before income taxes		3,459
(1) Presented is the period in which we have a membership interest in Constitution, and not prior periods when we had no membership interest in Constitution. Our membership in Constitution began in November 2012.

Variable_Interest_Entities

Variable Interest Entities	12 Months Ended
	Oct. 31, 2013
Variable Interest Entities [Abstract]	'
Aggregation Of Variable Interest Entities Disclosures [Text Block]	'
	13. Variable Interest Entities
	Under accounting guidance, a variable interest entity (VIE) is a legal entity that conducts a business or holds property whose equity, by design, has any of the following characteristics: an insufficient amount of equity at risk to finance its activities, equity owners who do not have the power to direct the significant activities of the entity (or have voting rights that are disproportionate to their ownership interest), or where equity owners do not receive expected losses or returns. An entity may have an interest in a VIE through ownership or other contractual rights or obligations and that interest changes as the entity's net assets change. The consolidating investor is the entity that has the power to direct the activities of a VIE that most significantly impact the VIE's economic performance, the obligation to absorb losses of the entity that could potentially be significant to the VIE or the right to receive benefits from the VIE that could potentially be significant to the VIE.
	As of October 31, 2013, we have determined that we are not the primary beneficiary, as defined by the authoritative guidance related to consolidations, in any of our equity method investments, as discussed in Note 12 to the consolidated financial statements. Based on our involvement in these investments, we do not have the power to direct the activities of these investments that most significantly impact the VIE's economic performance. As we are not the consolidating investor, we will continue to apply equity method accounting to these investments, as discussed in Note 12 to the consolidated financial statements. Our maximum loss exposure related to these equity method investments is limited to our equity investment in each entity. As of October 31, 2013 and 2012, our investment balances are as follows.
			October 31,		October 31,
	In thousands		2013		2012
	Cardinal	$	18,207	$	17,969
	Pine Needle		20,270		19,239
	SouthStar		38,372		18,118
	Hardy Storage		34,681		32,541
	Constitution		16,939		-
	Total equity method investments in non-utility activities	$	128,469	$	87,867
	We have also reviewed various lease arrangements, contracts to purchase, sell or deliver natural gas and other agreements in which we hold a variable interest. In these cases, we have determined that we are not the primary beneficiary of the related VIE because we do not have the power to direct the activities of the VIE that most significantly impact the VIE's economic performance, or the obligation to absorb losses of the VIE or the right to receive benefits from the VIE that could potentially be significant to the VIE.

Business_Segments

Business Segments	12 Months Ended
	Oct. 31, 2013
Business Segments Disclosure [Abstract]	'
Segment Reporting Disclosure Text Block	'
	14. Business Segments
	We have two reportable business segments, regulated utility and non-utility activities. Our segments are identified based on products and services, regulatory environments and our current corporate organization and business decision-making activities. The regulated utility segment is the gas distribution business, where we include the operations of merchandising and its related service work and home warranty programs, with activities conducted by the parent company. Operations of our non-utility activities segment are comprised of our equity method investments in joint ventures that are held by our wholly owned subsidiaries.
	Operations of the regulated utility segment are reflected in “Operating Income” in the Consolidated Statements of Comprehensive Income. Operations of the non-utility activities segment are included in the Consolidated Statements of Comprehensive Income in “Other Income (Expense)” in “Income from equity method investments” and “Non-operating income.” All of our operations are within the United States. No single customer accounts for more than 10% of our consolidated revenues.
	We evaluate the performance of the regulated utility segment based on margin, O&M expenses and operating income. We evaluate the performance of the non-utility activities segment based on earnings from and our cash flows in the ventures.
	Operations by segment for the years ended October 31, 2013, 2012 and 2011, and as of October 31, 2013, 2012 and 2011 are presented below.
		Regulated		Non-Utility
	In thousands	Utility		Activities		Total
	2013
	Revenues from external customers	$	1,278,229	$	-	$	1,278,229
	Margin		621,490		-		621,490
	Operations and maintenance expenses		253,120		181		253,301
	Depreciation		112,207		18		112,225
	Income from equity method investments		-		26,056		26,056
	Interest expense		24,938		-		24,938
	Operating income (loss) before income taxes		221,528		-352		221,176
	Income before income taxes		194,659		25,704		220,363
	Total assets		4,053,591		128,832		4,182,423
	Equity method investments in non-utility activities		-		128,469		128,469
	Construction expenditures		599,999		-		599,999
		Regulated		Non-Utility
	In thousands	Utility		Activities		Total
	2012
	Revenues from external customers	$	1,122,780	$	-	$	1,122,780
	Margin		575,446		-		575,446
	Operations and maintenance expenses		242,599		102		242,701
	Depreciation		103,192		18		103,210
	Income from equity method investments		-		23,904		23,904
	Interest expense		20,097		-		20,097
	Operating income (loss) before income taxes		194,824		-264		194,560
	Income before income taxes		174,424		23,640		198,064
	Total assets		3,475,640		88,247		3,563,887
	Equity method investments in non-utility activities		-		87,867		87,867
	Construction expenditures		529,576		-		529,576
		Regulated		Non-Utility
	In thousands	Utility		Activities		Total
	2011
	Revenues from external customers	$	1,433,905	$	-	$	1,433,905
	Margin		573,639		-		573,639
	Operations and maintenance expenses		225,351		109		225,460
	Depreciation		102,829		28		102,857
	Income from equity method investments		-		24,027		24,027
	Interest expense		43,992		-		43,992
	Operating income (loss) before income taxes		207,079		-120		206,959
	Income before income taxes		161,925		23,929		185,854
	Total assets		2,968,574		85,519		3,054,093
	Equity method investments in non-utility activities		-		85,121		85,121
	Construction expenditures		243,641		-		243,641
	Reconciliations to the consolidated financial statements for the years ended October 31, 2013, 2012 and 2011, and as of October 31, 2013 and 2012 are as follows.
	In thousands	2013		2012		2011
	Operating Income:
	Segment operating income before income taxes	$	221,176	$	194,560	$	206,959
	Utility income taxes		-77,334		-69,101		-64,068
	Non-utility activities operating loss before income taxes		352		264		120
	Total	$	144,194	$	125,723	$	143,011
	Net Income:
	Income before income taxes for reportable segments	$	220,363	$	198,064	$	185,854
	Income taxes		-85,946		-78,217		-72,286
	Total	$	134,417	$	119,847	$	113,568
	In thousands	2013		2012
	Consolidated Assets:
	Total assets for reportable segments	$	4,182,423	$	3,563,887
	Eliminations/Adjustments		186,186		206,052
	Total	$	4,368,609	$	3,769,939

Subsequent_Events

Subsequent Events	12 Months Ended
	Oct. 31, 2013
Subsequent Events Disclosure [Abstract]	'
Schedule Of Subsequent Events Text Block	'
	15. Subsequent Events
	We monitor significant events occurring after the balance sheet date and prior to the issuance of the financial statements to determine the impacts, if any, of events on the financial statements to be issued. All subsequent events of which we are aware were evaluated. For information on subsequent event disclosure items related to regulatory matters, stockholders' equity and environmental matters, see Note 2, Note 6 and Note 8, respectively, to the consolidated financial statements.

Selected_Quarterly_Financial_D

Selected Quarterly Financial Data	12 Months Ended
	Oct. 31, 2013
Quarterly Financial Data [Abstract]	'
Quarterly Financial Information Text Block	'
	16. Selected Quarterly Financial Data (In thousands except per share amounts) (Unaudited)
										Earnings (Loss)
						Operating		Net		Per Share of
		Operating				Income		Income		Common Stock
		Revenues		Margin		(Loss)		(Loss)		Basic		Diluted
	Fiscal Year 2013
	31-Jan	$	515,875	$	231,623	$	86,213	$	85,923	$	1.19	$	1.18
	30-Apr		399,411		183,856		51,504		55,790		0.74		0.74
	31-Jul		162,943		97,000		591		-2,293		-0.03		-0.03
	31-Oct		200,000		109,011		5,886		-5,003		-0.07		-0.07
	Fiscal Year 2012
	31-Jan	$	471,840	$	220,237	$	79,819	$	76,227	$	1.06	$	1.05
	30-Apr		308,432		171,951		48,782		50,192		0.7		0.7
	31-Jul		161,123		86,460		-2,513		-4,613		-0.06		-0.06
	31-Oct		181,385		96,798		-365		-1,959		-0.03		-0.03
	The pattern of quarterly earnings is the result of the highly seasonal nature of the business as variations in weather conditions and our regulated utility rate designs generally result in greater earnings during the winter months. Basic earnings per share are calculated using the weighted average number of shares outstanding during the quarter. The annual amount may differ from the total of the quarterly amounts due to changes in the number of shares outstanding during the year.

Recovered_Sheet2

Summary Of Significant Accounting Policies (Policies)	12 Months Ended
	Oct. 31, 2013
Summary Of Significant Accounting Policies Disclosure [Abstract]	'
Operations And Principles Of Consolidation	'
	The consolidated financial statements reflect the accounts of Piedmont and its wholly owned subsidiaries whose financial statements are prepared for the same reporting period as Piedmont using consistent accounting policies. Investments in non-utility activities, or joint ventures, are accounted for under the equity method as we do not have controlling voting interests or otherwise exercise control over the management of such companies.
	Inter-company transactions have been eliminated in consolidation where appropriate; however, we have not eliminated inter-company profit on sales to affiliates and costs from affiliates in accordance with accounting regulations prescribed under rate-based regulation.
	The consolidated financial statements of Piedmont have been prepared in conformity with generally accepted accounting principles in the United States of America (GAAP) and under the rules of the Securities and Exchange Commission (SEC).
Segment Reporting, Policy	'
	Our segments are based on the components of the Company that are evaluated regularly by the chief operating decision maker in deciding how to allocate resources and in assessing performance. Our chief operating decision maker is the executive management team comprised of senior level management. Our segments are identified based on products and services, regulatory environments and our current corporate organization and business decision-making activities. We evaluate the performance of the regulated utility segment based on margin, operations and maintenance (O&M) expenses and operating income. We evaluate the performance of the non-utility activities segment based on earnings from the ventures.
Rate Regulated Basis Of Accounting	'
	Our utility operations are subject to regulation with respect to rates, service area, accounting and various other matters by the regulatory commissions in the states in which we operate. The accounting regulations provide that rate-regulated public utilities account for and report assets and liabilities consistent with the economic effect of the manner in which independent third-party regulators establish rates. In applying these regulations, we capitalize certain costs and benefits as regulatory assets and liabilities, respectively, in order to provide for recovery from or refund to utility customers in future periods.
	Our regulatory assets are recoverable through either base rates or rate riders specifically authorized by a state regulatory commission. Base rates are designed to provide both a recovery of cost and a return on investment during the period the rates are in effect. As such, all of our regulatory assets are subject to review by the respective state regulatory commissions during any future rate proceedings. In the event that accounting for the effects of regulation were no longer applicable, we would recognize a write-off of the regulatory assets and regulatory liabilities that would result in an adjustment to net income. Our utility operations continue to recover their costs through cost-based rates established by the state regulatory commissions.
Utility Plant And Depreciation	'
	Utility plant is stated at original cost, including direct labor and materials, contractor costs, allocable overhead charges, such as engineering, supervision, corporate office salaries and expenses, and pensions and insurance, and an allowance for funds used during construction (AFUDC) that is calculated under a formula prescribed by our state regulators. We apply the group method of accounting, where the costs of homogeneous assets are aggregated and depreciated by applying a rate based on the average expected useful life of the assets. Major expenditures that last longer than a year and improve or lengthen the expected useful life of the overall property from original expectations that are recoverable in regulatory rate base are capitalized while expenditures not meeting these criteria are expensed as incurred. The costs of property retired or otherwise disposed of are removed from utility plant and charged to accumulated depreciation for recovery or refund through future rates. On certain assets, like land, that are nondepreciable, we record a gain or loss upon the disposal of the property
	We compute depreciation expense using the straight-line method
	As authorized by our regulatory commissions, the estimated costs of removal on certain regulated properties are collected through depreciation expense through rates with a corresponding credit to accumulated depreciation. Our approved depreciation rates are comprised of two components, one based on average service life and one based on cost of removal for certain regulated properties. Therefore, through depreciation expense, we collect and record estimated non-legal costs of removal on any depreciable asset that includes cost of removal in its depreciation rate.
	Depreciation rates for utility plant are approved by our regulatory commissions.
Asset Retirement Obligations Policy	'
	The estimated cash flows to settle conditional AROs are discounted using the credit adjusted risk-free rate
	We apply the accounting guidance for conditional AROs that requires recognition of a liability for the fair value of conditional AROs when incurred if the liability can be reasonably estimated. The NCUC, the PSCSC and the TRA have approved placing these ARO costs in deferred accounts to preserve the regulatory treatment of these costs;
Cash and Cash Equivalents, Policy	'
	We consider instruments purchased with an original maturity at date of purchase of three months or less to be cash equivalents, particularly affecting the Consolidated Statements of Cash Flows.
Trade Receivables And Allowance For Doubtful Accounts	'
	Our policy requires counterparties to have an investment-grade credit rating at the time of the contract. In situations where counterparties do not have investment grade or functionally equivalent credit ratings, our policy requires credit enhancements that include letters of credit or parental guaranties. In either circumstance, the policy specifies limits on the contract amount and duration based on the counterparty's credit rating and/or credit support.
	Trade accounts receivable consist of natural gas sales and transportation services, merchandise sales and service work. We bill customers monthly with payment due within 30 days. We maintain an allowance for doubtful accounts, which we adjust periodically, based on the aging of receivables and our historical and projected charge-off activity.
	We write off our customers' accounts when they are deemed to be uncollectible. Pursuant to orders issued by the NCUC, the Public Service Commission of South Carolina (PSCSC) and the TRA, we are authorized to recover all uncollected gas costs through the purchased gas adjustment (PGA).
Fair Value Measurements	'
	The carrying values of cash and cash equivalents, receivables, short-term debt, accounts payable, accrued interest and other current liabilities approximate fair value as all amounts reported are to be collected or paid within one year. Our financial assets and liabilities are recorded at fair value.
	Our qualified pension and postretirement plan assets and liabilities are recorded at fair value in the Consolidated Balance Sheets in accordance with employers' accounting and related disclosures of postretirement plans.
	We utilize market data or assumptions that market participants would use in valuing the asset or liability, including assumptions about risk and the risks inherent in the inputs to the valuation technique. These inputs can be readily observable, market corroborated or generally unobservable. We primarily apply the market approach for fair value measurements and endeavor to utilize the best available information. Accordingly, we use valuation techniques that maximize the use of observable inputs and minimize the use of unobservable inputs.
	We are able to classify fair value balances based on the observance of those inputs at the lowest level that is significant to the fair value measurement, in its entirety, in
	fair value hierarchy levels as set forth in the fair value guidance.
	We obtain market price data from multiple sources in order to value some of our Level 2 transactions and this data is representative of transactions that occurred in the marketplace.
	For some qualified pension plan assets, the determination of Level 2 assets was completed through a process of reviewing each individual security while consulting research and other metrics provided by investment managers, including a pricing matrix detailing the pricing source and security type, annual audited financial statements and a review of valuation policies and procedures used by the investment managers as well as our investment advisor.
	In determining whether to categorize the fair value measurement of an instrument as Level 2 or Level 3, we must use judgment to assess whether we have the ability as of the measurement date to redeem an investment at its net asset value per share (NAV) in the near term. We consider when we might have the ability to redeem the investment by reviewing contractual restrictions in effect as of the investment date as well as any potential restrictions that the investee may impose. Regarding our benefit plans' investments, “near term” is the ability to redeem an investment in no more than 180 days.
	Transfers between different levels of the fair value hierarchy may occur based on the level of observable inputs used to value the instruments for the period. These transfers represent existing assets or liabilities previously categorized as a Level 1 or Level 2 for which the inputs to the estimate became less observable or assets and liabilities previously classified as Level 2 or Level 3 for which the lowest significant input became more observable during the period. Transfers into and out of each level are measured at the actual date of the event or change in circumstances causing the transfer.
Goodwill and Intangible Assets, Goodwill, Policy	'
	Goodwill is the excess of the purchase price over the fair value of identifiable net assets acquired in a business combination. We annually evaluate goodwill for impairment as of October 31, or more frequently if impairment indicators arise during the year. These indicators include, but are not limited to, a significant change in operating performance, the business climate, legal or regulatory factors, or a planned sale or disposition of a significant portion of the business. We test goodwill using a fair value approach at a reporting unit level, generally equivalent to our operating segments as discussed in Note 14 to the consolidated financial statements. An impairment charge would be recognized if the carrying value of the reporting unit, including goodwill, exceeded its fair value.
Equity Method Investments And Long Lived Assets Policy	'
	We review our equity method investments and long-lived assets for impairment whenever events or changes in circumstances indicate that the carrying amounts may not be recoverable.
Unamortized Debt Expense	'
	Unamortized debt expense consists of costs, such as underwriting and broker dealer fees, discounts and commissions, legal fees, accountant fees, registration fees and rating agency fees, related to issuing long-term debt and the short-term syndicated revolving credit facility. We amortize long-term debt expense on a straight-line basis, which approximates the effective interest method, over the life of the related debt
	We amortize bank debt expense over the life of the syndicated revolving credit facility
	Should we reacquire long-term debt prior to its term date and simultaneously issue new debt, we defer the gain or loss resulting from the transaction, essentially the remaining unamortized debt expense, and amortize it over the life of the new debt in accordance with established regulatory practice. Where the refunding of the debt is not simultaneous, we defer the gain or loss resulting from the reacquisition of the debt and amortize it over the remaining life of the redeemed debt in accordance with established regulatory practice. For income tax purposes, any gain or loss would be recognized as incurred.
Inventories	'
	Materials, supplies and merchandise inventories are valued at the lower of average cost or market and removed from such inventory at average cost.
	Under the terms of the agreements, we receive asset management fees, which are recorded as secondary market transactions and shared between our utility customers and our shareholders.
	We maintain gas inventories on the basis of average cost. Injections into storage are priced at the purchase cost at the time of injection, and withdrawals from storage are priced at the weighted average purchase price in storage. The cost of gas in storage is recoverable under rate schedules approved by state regulatory commissions. Inventory activity is subject to regulatory review on an annual basis in gas cost recovery proceedings.
Deferred Purchased Gas Adjustments Policy Disclosure	'
	We charge our utility customers for natural gas consumed using natural gas cost recovery mechanisms as set by the regulatory commissions in states in which we operate. Rate schedules for utility sales and transportation customers include PGA provisions that provide for the recovery of prudently incurred gas costs. With regulatory commission approval, we revise rates periodically without formal rate proceedings to reflect changes in the wholesale cost of gas. We charge our secondary market customers for natural gas based on negotiated contract terms. Under PGA provisions, charges to cost of gas are based on the amount recoverable under approved rate schedules. Within our cost of gas, we include amounts for lost and unaccounted for gas and adjustments to reflect the gains and losses associated with gas price hedging derivatives.
	We review gas costs and deferral activity periodically (including deferrals under the margin decoupling and WNA mechanisms) and, with regulatory commission approval, increase rates to collect under-recoveries or decrease rates to refund over-recoveries over a subsequent period.
Marketable Securities	'
	We have classified these marketable securities as trading securities since their inception as the assets are held in rabbi trusts. Trading securities are recorded at fair value on the Consolidated Balance Sheets with any gains or losses recognized currently in earnings.
	The money market investments in the trusts approximate fair value due to the short period of time to maturity. The fair values of the equity securities are based on quoted market prices as traded on the exchanges.
Taxes	'
	We have two categories of income taxes in the Consolidated Statements of Comprehensive Income: current and deferred. Current income tax expense consists of federal and state income taxes less applicable tax credits related to the current year.
	Deferred income taxes are determined based on the estimated future tax effects of differences between the book and tax basis of assets and liabilities. We have provided valuation allowances to reduce the carrying amount of deferred tax assets to amounts that are more likely than not to be realized. To the extent that the establishment of deferred income taxes is different from the recovery of taxes through the ratemaking process, the differences are deferred in accordance with rate-regulated accounting provisions, and a regulatory asset or liability is recognized for the impact of tax expenses or benefits that will be collected from or refunded to customers in different periods pursuant to rate orders.
	We amortize these deferred investment and energy tax credits to income over the estimated useful lives of the property to which the credits relate.
	We recognize accrued interest and penalties, if any, related to uncertain tax positions as operating expenses in the Consolidated Statements of Comprehensive Income.
	Excise taxes, sales taxes and franchises fees separately stated on customer bills are recorded on a net basis as liabilities payable to the applicable jurisdictions. All other taxes other than income taxes are recorded as general taxes. General taxes consist of property taxes, payroll taxes, Tennessee gross receipt taxes, franchise taxes, tax on company use and other miscellaneous taxes.
Revenue Recognition	'
	Utility sales, transportation and secondary market revenues are reported net of excise taxes, sales taxes and franchise fees.
	Non-regulated merchandise and service work includes the sale, installation and/or maintenance of natural gas appliances and gas piping beyond the meter. Revenue is recognized when the sale is made or the work is performed. If the customer is eligible for and elects financing through us, the finance fee income is recognized on a monthly basis based on principal, rate and term.
	We record revenues when services are provided to our distribution service customers. Utility sales and transportation revenues are based on rates approved by state regulatory commissions. Base rates charged to jurisdictional customers may not be changed without approval by the regulatory commission in that jurisdiction; however, the wholesale cost of gas component of rates may be adjusted periodically under PGA provisions.
	Revenues are recognized monthly on the accrual basis, which includes estimated amounts for gas delivered to customers but not yet billed under the cycle-billing method from the last meter reading date to month end.
	Secondary market revenues associated with the commodity are recognized when the physical sales are delivered based on contract or market prices. Asset management fees for storage and transportation remitted on a monthly basis are recognized as earned given the monthly capacity costs associated with the contracts involved. Asset management fees remitted in a lump sum are deferred and amortized ratably into income over the period in which they are earned, which is typically the contract term.
Statement Of Cash Flows	'
	With respect to cash overdrafts, book overdrafts are included within operating cash flows while any bank overdrafts are included with financing cash flows.
Use of Estimates	'
	In accordance with GAAP, we make certain estimates and assumptions regarding reported amounts of assets and liabilities, disclosure of contingent assets and liabilities as of the date of the consolidated financial statements, and reported amounts of revenues and expenses during the periods reported. Actual results could differ significantly from estimates and assumptions.
Subsequent Events Policy	'
	We monitor significant events occurring after the balance sheet date and prior to the issuance of the financial statements to determine the impacts, if any, of events on the financial statements to be issued. All subsequent events of which we are aware were evaluated.
Common Stock Issuance and Repurchase Policy	'
	we repurchase shares on the open market and such shares are then cancelled and become authorized but unissued shares. It is our policy to issue new shares for share-based employee awards and shareholder and employee investment plans.
Earnings Per Share	'
	We compute basic EPS using the weighted average number of shares of common stock outstanding during each period. Shares of common stock to be issued under approved incentive compensation plans and forward sale agreements are contingently issuable shares, as determined by applying the treasury stock method, and are included in our calculation of fully diluted EPS.

Summary_Of_Significant_Account1

Summary Of Significant Accounting Policies (Tables)	12 Months Ended
	Oct. 31, 2013
Summary Of Significant Accounting Policies Disclosure [Abstract]	'
Schedule of Regulatory Assets [Table Text Block]	'
	Regulatory assets and liabilities in the Consolidated Balance Sheets as of October 31, 2013 and 2012 are as follows.
	In thousands	2013			2012
	Regulatory Assets:
	Unamortized debt expense	$	15,423		$	13,583
	Amounts due from customers		66,321			81,626
	Environmental costs		9,416			10,202
	Deferred operations and maintenance expenses		6,376			7,050
	Deferred pipeline integrity expenses		19,449			13,691
	Deferred pension and other retirement benefits costs		20,736			20,139
	Amounts not yet recognized as a component of pension
	and other retirement benefit costs		80,604			123,290
	Regulatory cost of removal asset		22,974			21,129
	Robeson LNG development costs		1,808			-
	Other		3,199			2,394
	Total	$	246,306		$	293,104
Schedule of Regulatory Liabilities [Table Text Block]	'
	Regulatory Liabilities:
	Regulatory cost of removal obligations	$	493,111		$	464,334
	Amounts due to customers		-			28
	Deferred income taxes		48,647			25,330
	Amounts not yet recognized as a component of pension
	and other retirement costs		139			-
	Total	$	541,897		$	489,692
Schedule of Public Utility Property, Plant, and Equipment [Table Text Block]	'
	The classification of total utility plant, net, for the years ended October 31, 2013 and 2012 is presented below.
	In thousands		2013			2012
	Intangible plant		$	3,374		$	3,374
	Other storage plant			171,349			118,277
	Transmission plant			1,403,829			866,000
	Distribution plant			2,505,160			2,422,988
	General plant			335,847			329,867
	Asset retirement cost			7,565			10,819
	Contributions in aid of construction			-5,187			-5,147
	Total utility plant in service			4,421,937			3,746,178
	Less accumulated depreciation			-1,088,331			-1,036,814
	Total utility plant in service, net			3,333,606			2,709,364
	Construction work in progress			297,717			388,979
	Plant held for future use			3,155			6,743
	Total utility plant, net		$	3,634,478		$	3,105,086
Allowance For Funds Used During Construction [Table Text Block]	'
	AFUDC for the years ended October 31, 2013, 2012 and 2011 is presented below.
	In thousands		2013			2012			2011
	AFUDC		$30,975			$25,211			$8,619
Financing Receivable Detail [Table Text Block]	'
	As of October 31, 2013 and 2012, our trade accounts receivable consisted of the following.
	In thousands			2013			2012
	Gas receivables		$	78,540		$	55,956
	Non-regulated merchandise and service work receivables			2,274			2,323
	Allowance for doubtful accounts			-1,604			-1,579
	Trade accounts receivable		$	79,210		$	56,700
Reconciliation of Allowance for Doubtful Accounts [Table Text Block]	'
	A reconciliation of the changes in the allowance for doubtful accounts for the years ended October 31, 2013, 2012 and 2011 is presented below.
	In thousands					2013			2012		2011
	Balance at beginning of year				$	1,579		$	1,347	$	929
	Additions charged to uncollectibles expense					5,314			4,584		4,842
	Accounts written off, net of recoveries					-5,289			-4,352		-4,424
	Balance at end of year				$	1,604		$	1,579	$	1,347
Schedule Marketable Securities Contained In Rabbi Trust [Table Text Block]	'
	The composition of these securities as of October 31, 2013 and 2012 is as follows.
	In thousands	2013						2012
		Cost			Fair Value			Cost		Fair Value
	Current trading securities:
	Money markets	$	-		$	-		$	-	$	-
	Mutual funds		134			199			134		157
	Total current trading securities		134			199			134		157
	Noncurrent trading securities:
	Money markets		380			380			243		243
	Mutual funds		1,995			2,615			1,668		1,888
	Total noncurrent trading securities		2,375			2,995			1,911		2,131
	Total trading securities	$	2,509		$	3,194		$	2,045	$	2,288
Schedule of Asset Retirement Obligations [Table Text Block]	'
	The cost of removal obligations recorded in the Consolidated Balance Sheets as of October 31, 2013 and 2012 are presented below.
	In thousands	2013			2012
	Regulatory non-legal AROs	$	493,111		$	464,334
	Conditional AROs		27,016			28,629
	Total cost of removal obligations	$	520,127		$	492,963
Asset Retirement Obligations Reconciliation [Table Text Block]	'
	A reconciliation of the changes in conditional AROs for the year ended October 31, 2013 and 2012 is presented below.
	In thousands		2013			2012
	Beginning of period		$	28,629		$	27,395
	Liabilities incurred during the period			2,052			1,705
	Liabilities settled during the period			-2,389			-2,038
	Accretion			1,641			1,570
	Adjustment to estimated cash flows			-2,917			-3
	End of period		$	27,016		$	28,629

Earnings_Per_Share_Tables

Earnings Per Share (Tables)	12 Months Ended
	Oct. 31, 2013
Earnings Per Share of Common Stock	'
Schedule Of Earnings Per Share Basic And Diluted [Table Text Block]	'
	A reconciliation of basic and diluted EPS for the years ended October 31, 2013, 2012 and 2011 is presented below.
	In thousands except per share amounts	2013		2012		2011
	Net Income	$	134,417	$	119,847	$	113,568
	Average shares of common stock outstanding for basic
	earnings per share		74,884		71,977		72,056
	Contingently issuable shares under incentive compensation plans		289		301		210
	Contingently issuable shares under forward sale agreements		160		-		-
	Average shares of dilutive stock		75,333		72,278		72,266
	Earnings Per Share of Common Stock:
	Basic	$	1.8	$	1.67	$	1.58
	Diluted	$	1.78	$	1.66	$	1.57

Long_Term_Debt_Tables

Long Term Debt (Tables)	12 Months Ended
	Oct. 31, 2013
Long Term Debt Abstract	'
Schedule of Long-term Debt Instruments [Table Text Block]	'
	Long-term debt as of October 31, 2013 and 2012 is as follows.
	In thousands	2013		2012
	Senior Notes:
	2.92%, due June 6, 2016	$	40,000	$	40,000
	8.51%, due September 30, 2017		35,000		35,000
	4.24%, due June 6, 2021		160,000		160,000
	3.47%, due July 16, 2027		100,000		100,000
	3.57%, due July 16, 2027		200,000		200,000
	4.65%, due August 1, 2043		300,000		-
	Medium-Term Notes:
	5.00%, due December 19, 2013		100,000		100,000
	6.87%, due October 6, 2023		45,000		45,000
	8.45%, due September 19, 2024		40,000		40,000
	7.40%, due October 3, 2025		55,000		55,000
	7.50%, due October 9, 2026		40,000		40,000
	7.95%, due September 14, 2029		60,000		60,000
	6.00%, due December 19, 2033		100,000		100,000
	Total		1,275,000		975,000
	Less current maturities		100,000		-
	Less discount on issuance of notes		143		-
	Total	$	1,174,857	$	975,000
Schedule of Maturities of Long-term Debt [Table Text Block]	'
	Current maturities for the next five years ending October 31 and thereafter are as follows.
	In thousands
	2014	$	100,000
	2015		-
	2016		40,000
	2017		35,000
	2018		-
	Thereafter		1,100,000
	Total	$	1,275,000
Schedule Of Whether Any Payments Restricted By Earnings [Table Text Block]	'
	As of October 31, 2013, our retained earnings were not restricted as the amount available for restricted payments was greater than our actual retained earnings as presented below.
	In thousands
	Amount available for restricted payments	$	760,870
	Retained earnings		627,236

Short_Term_Debt_Tables

Short Term Debt (Tables)	12 Months Ended
	Oct. 31, 2013
Short Term Debt Disclosure [Abstract]	'
ScheduleOfLineOfCreditFacilitiesTextBlock	'
	A summary of the short-term debt activity for the twelve months ended October 31, 2013 is as follows.
		Short-Term Debt Activity
			Credit			Commercial			Total
	In thousands		Facility			Paper			Borrowings
		Minimum amount outstanding (1)	$	-		$	220,000		$	220,000
		Maximum amount outstanding (1)	$	10,000		$	555,000		$	555,000
		Minimum interest rate (2)		1.12	%		0.23	%		0.23	%
		Maximum interest rate		1.12	%		0.45	%		1.12	%
		Weighted average interest rate		1.12	%		0.32	%		0.32	%
		(1) During December 2012, we were borrowing under both the credit facility and CP program for a portion of the month.
		(2) This is the minimum rate when we were borrowing under the credit facility and/or CP program.

Stockholders_Equity_Tables

Stockholders' Equity (Tables)	12 Months Ended
	Oct. 31, 2013
Stockholders' Equity [Abstract]	'
Schedule Of Capital Stock And Accelerated Share Repurchases [Table Text Block]	'
	Changes in common stock for the years ended October 31, 2013, 2012 and 2011 are as follows.
	In thousands	Shares		Amount
	Balance, October 31, 2010	72,282		$	445,640
	Issued to participants in the Employee Stock Purchase Plan (ESPP)	30			870
	Issued to the Dividend Reinvestment and Stock Purchase Plan (DRIP)	657			18,834
	Issued to participants in the Incentive Compensation Plan (ICP)	149			4,451
	Shares repurchased under Accelerated Share Repurchase (ASR) agreement	-800			-23,004
	Balance, October 31, 2011	72,318			446,791
	Issued to ESPP	30			894
	Issued to DRIP	677			20,508
	Issued to ICP	25			796
	Shares repurchased under ASR agreement	-800			-26,528
	Balance, October 31, 2012	72,250			442,461
	Issued to ESPP	33			1,056
	Issued to DRIP	720			22,791
	Issued to ICP	96			3,065
	Issuance of common stock through public share offering, net of underwriting fees	3,000			92,640
	Costs from issuance of common stock	-			-369
	Balance, October 31, 2013	76,099		$	561,644
Schedule Shares Reserved For Issuance [Table Text Block]	'
	As of October 31, 2013, our shares of common stock were reserved for issuance as follows.
	In thousands
	ESPP	210
	DRIP	1,538
	ICP	1,050
	Total	2,798
ScheduleOfAccumulated Other Comprehensive Income Loss [Table Text Block]	'
	Changes in each component of accumulated OCIL are presented below for the years ended October 31, 2013 and 2012.
	Changes in Accumulated OCIL (1)
	In thousands
	Balance, October 31, 2011		$	-452
	OCIL before reclassifications, net of tax			-826
	Amounts reclassified from accumulated OCIL, net of tax			973
	Total current period activity, net of tax			147
	Balance, October 31, 2012			-305
	OCIL before reclassifications, net of tax			-109
	Amounts reclassified from accumulated OCIL, net of tax			130
	Total current period activity, net of tax			21
	Balance, October 31, 2013		$	-284
	(1) Amounts in parentheses indicate debits to accumulated OCIL.
Reclassification Out Of Accumulated Other Comprehensive Income [Table Text Block]	'
	A reconciliation of the effect on certain line items of net income on amounts reclassified out of each component of accumulated OCIL is presented below for the years ended October 31, 2013 and 2012.
		Reclassifications Out of
		Accumulated OCIL (1)
		Years Ended
		October 31,					Affected Line Items on Statement of
	In thousands	2013			2012		Comprehensive Income
	Hedging activities of equity method investments	$	-215		$	-1,594	Income from equity method investments
	Income tax expense		85			621	Income taxes
	Total reclassification for the period, net of tax	$	-130		$	-973
	(1) Amounts in parentheses indicate credits to accumulated OCIL.

Financial_Instruments_Related_

Financial Instruments & Related Fair Value (Tables)	12 Months Ended
	Oct. 31, 2013
Financial Instruments And Related Fair Value Tables [Abstract]	'
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis [Table Text Block]	'
	The following table sets forth, by level of the fair value hierarchy, our financial assets and liabilities that were accounted for at fair value on a recurring basis as of October 31, 2013 and 2012.
	Recurring Fair Value Measurements as of October 31, 2013
					Significant
			Quoted Prices		Other			Significant
			in Active		Observable			Unobservable		Total
			Markets		Inputs			Inputs		Carrying
	In thousands		(Level 1)		(Level 2)			(Level 3)		Value
	Assets:
	Derivatives held for distribution operations	$	1,834	$	-		$	-	$	1,834
	Debt and equity securities held as trading securities:
	Money markets		380		-			-		380
	Mutual funds		2,814		-			-		2,814
	Total fair value assets	$	5,028	$	-		$	-	$	5,028
	Recurring Fair Value Measurements as of October 31, 2012
					Significant
			Quoted Prices		Other			Significant
			in Active		Observable			Unobservable		Total
			Markets		Inputs			Inputs		Carrying
	In thousands		(Level 1)		(Level 2)			(Level 3)		Value
	Assets:
	Derivatives held for distribution operations	$	3,153	$	-		$	-	$	3,153
	Debt and equity securities held as trading securities:
	Money markets		243		-			-		243
	Mutual funds		2,045		-			-		2,045
	Total fair value assets	$	5,441	$	-		$	-	$	5,441
Fair Value, by Balance Sheet Grouping [Table Text Block]	'
	The carrying amount and fair value of our long-term debt, including the current portion, which is classified within Level 2, are shown below.
			Carrying
	In thousands		Amount		Fair Value
	As of October 31, 2013	$	1,275,000	$	1,409,892
	As of October 31, 2012		975,000		1,163,227
	The following table presents the fair value and balance sheet classification of our financial options for natural gas as of October 31, 2013 and 2012.
	Fair Value of Derivative Instruments
	In thousands					2013				2012
	Derivatives Not Designated as Hedging Instruments under Derivative Accounting Standards:
	Asset Financial Instruments:
	Current Assets - Gas purchase derivative assets (December 2013 - October 2014)					$	1,834
	Current Assets - Gas purchase derivative assets (December 2012 - October 2013)								$	3,153
Fair Value, Assets and Liabilities Measured on Recurring Basis, Gain (Loss) Included in Earnings [Table Text Block]	'
	The following table presents the impact that financial instruments not designated as hedging instruments under derivative accounting standards would have had on the Consolidated Statements of Comprehensive Income for the twelve months ended October 31, 2013 and 2012, absent the regulatory treatment under our approved PGA procedures.
											Location of Loss
		Amount of Loss Recognized					Amount of Loss Deferred				Recognized through
	In thousands	on Derivative Instruments					Under PGA Procedures				PGA Procedures
			Twelve Months Ended					Twelve Months Ended
			31-Oct					31-Oct
			2013		2012			2013		2012
	Gas purchase options	$	6,303	$	8		$	6,303	$	8	Cost of Gas

Commitment_Contingencies_Table

Commitment & Contingencies (Tables)	12 Months Ended
	Oct. 31, 2013
Commitments and Contingencies Disclosure [Abstract]	'
Schedule of Operating Lease Payments [Table Text Block]	'
	Operating lease payments for the years ended October 31, 2013, 2012 and 2011 are as follows.
	In thousands		2013			2012			2011
	Operating lease payments (1)		$	4,729		$	3,712		$	4,496
	(1) Operating lease payments do not include payments for common area maintenance, utilities or tax payments.
Schedule of Future Minimum Rental Payments for Operating Leases [Table Text Block]	'
	Future minimum lease obligations for the next five years ending October 31 and thereafter are as follows.
	In thousands
	2014	$	4,543
	2015		4,592
	2016		4,491
	2017		4,297
	2018		4,225
	Thereafter		31,496
	Total	$	53,644
Long-term Purchase Commitment [Table Text Block]	'
	As of October 31, 2013, future unconditional purchase obligations for the next five years ending October 31 and thereafter are as follows.
		Pipeline and						Telecommunications
		Storage						and Information
	In thousands	Capacity			Gas Supply			Technology			Other		Total
	2014	$	170,430		$	6,356		$	11,045		$	24,951	$	212,782
	2015		157,407			-			4,676			-		162,083
	2016		150,544			-			760			-		151,304
	2017		145,494			-			-			-		145,494
	2018		142,983			-			-			-		142,983
	Thereafter		781,549			-			-			-		781,549
	Total	$	1,548,407		$	6,356		$	16,481		$	24,951	$	1,596,195

Employee_Benefit_Plans_Tables

Employee Benefit Plans (Tables)	12 Months Ended
	Oct. 31, 2013
Employee Benefit Plans Disclosure [Abstract]	'
Supplemental Executive Retirement Plans	'
	The funding to the DCR plan accounts for the years ended October 31, 2013 and 2012, and the amounts recorded as liabilities for these deferred compensation plans as of October 31, 2013 and 2012 are presented below.
	In thousands			2013			2012
	Funding		$	434		$	422
	Liability:
	Current			199			160
	Noncurrent			3,328			2,412
Term Life Insurance Premiums	'
	The cost of these premiums is presented below.
	In thousands		2013			2012			2011
	Term life policies of certain officers at the vice president
	level and above	$	27		$	43		$	56
	Officers and director-level employees		28			25			24
Reconciliation Of Changes In The Plans' Benefit Obligations And Fair Value Of Assets; Statement Of The Funded Status And The Amounts Reflected In The Consolidated Balance Sheets	'
	A reconciliation of changes in the plans' benefit obligations and fair value of assets for the years ended October 31, 2013 and 2012, and a statement of the funded status and the amounts reflected in the Consolidated Balance Sheets for the years ended October 31, 2013 and 2012 are presented below.
		Qualified Pension						Nonqualified Pension					Other Benefits
	In thousands	2013			2012			2013			2012		2013		2012
	Accumulated benefit obligation at year end	$	230,175		$	245,361		$	4,736		$	5,569		N/A		N/A
	Change in projected benefit obligation:
	Obligation at beginning of year	$	293,327		$	236,632		$	5,569		$	5,219	$	34,830	$	31,900
	Service cost		12,005			9,573			-			39		1,327		1,387
	Interest cost		9,946			10,640			157			203		1,130		1,347
	Actuarial (gain) loss		-24,859			54,852			-540			629		-1,094		2,630
	Participant contributions		-			-			-			-		641		788
	Administrative expenses		-534			-420			-			-		-		-
	Benefit payments		-17,482			-17,950			-450			-521		-3,156		-3,222
	Obligation at end of year		272,403			293,327			4,736			5,569		33,678		34,830
	Change in fair value of plan assets:
	Fair value at beginning of year		272,337			259,511			-			-		23,663		22,045
	Actual return on plan assets		26,340			31,196			-			-		2,848		1,972
	Employer contributions		20,000			-			450			521		1,965		2,080
	Participant contributions		-			-			-			-		641		788
	Administrative expenses		-534			-420			-			-		-		-
	Benefit payments		-17,482			-17,950			-450			-521		-3,156		-3,222
	Fair value at end of year		300,661			272,337			-			-		25,961		23,663
	Funded status at year end - (under) over	$	28,258		$	-20,990		$	-4,736		$	-5,569	$	-7,717	$	-11,167
	Noncurrent assets	$	28,258		$	-		$	-		$	-	$	-	$	-
	Current liabilities		-			-			-445			-502		-		-
	Noncurrent liabilities		-			-20,990			-4,291			-5,067		-7,717		-11,167
	Net amount recognized	$	28,258		$	-20,990		$	-4,736		$	-5,569	$	-7,717	$	-11,167
	Amounts Not Yet Recognized as a Component
	of Cost and Recognized in a Deferred
	Regulatory Account:
	Unrecognized transition obligation	$	-		$	-		$	-		$	-	$	-	$	-667
	Unrecognized prior service (cost) credit		17,243			19,441			-196			-277		-		-
	Unrecognized actuarial loss		-96,338			-137,633			-820			-1,521		-354		-2,633
	Regulatory asset		-79,095			-118,192			-1,016			-1,798		-354		-3,300
	Cumulative employer contributions in
	excess of cost		107,353			97,202			-3,720			-3,771		-7,363		-7,867
	Net amount recognized	$	28,258		$	-20,990		$	-4,736		$	-5,569	$	-7,717	$	-11,167
Components Of Net Periodic Benefit Cost	'
	Net periodic benefit cost for the years ended October 31, 2013, 2012 and 2011 includes the following components.
		Qualified Pension									Nonqualified Pension						Other Benefits
	In thousands	2013			2012			2011			2013		2012		2011		2013		2012		2011
	Service cost	$	12,005		$	9,573		$	8,508		$	-	$	39	$	45	$	1,327	$	1,387	$	1,398
	Interest cost		9,946			10,640			11,024			157		203		209		1,130		1,347		1,495
	Expected return on plan
	assets		-21,105			-20,289			-20,608			-		-		-		-1,663		-1,551		-1,534
	Amortization of transition
	obligation		-			-			-			-		-		-		667		667		667
	Amortization of prior
	service cost (credit)		-2,198			-2,198			-2,198			81		81		20		-		-		-
	Amortization of net loss		11,202			5,966			3,547			161		49		41		-		-		-
	Net periodic benefit cost		9,850			3,692			273			399		372		315		1,461		1,850		2,026
	Other changes in plan
	assets and benefit
	obligation recognized
	through regulatory asset
	or liability:
	Prior service cost		-			-			-			-		-		290		-		-		-
	Net loss (gain)		-30,094			43,945			17,539			-540		629		130		-2,278		2,209		415
	Amounts recognized as a
	component of net periodic
	benefit cost:
	Transition obligation		-			-			-			-		-		-		-667		-667		-667
	Amortization of net loss		-11,202			-5,966			-3,547			-161		-49		-41		-		-		-
	Prior service (cost) credit		2,198			2,198			2,198			-81		-81		-20		-		-		-
	Total recognized in
	regulatory asset (liability)		-39,098			40,177			16,190			-782		499		359		-2,945		1,542		-252
	Total recognized in net
	periodic benefit cost and
	regulatory asset (liability)	$	-29,248		$	43,869		$	16,463		$	-383	$	871	$	674	$	-1,484	$	3,392	$	1,774
Amortization Recorded As A Regulatory Asset Or Liability Expected Refunds For Defined Benefit Plans	'
	The 2014 estimated amortization of the following items for our plans, which are recorded as a regulatory asset or liability instead of accumulated OCIL discussed above, are as follows.
	In thousands	Qualified Pension			Nonqualified Pension			Other Benefits
	Amortization of unrecognized prior service cost (credit)	$	-2,198		$	81		$	-
	Amortization of unrecognized actuarial loss		7,138			47			-
Benefit Obligation Benchmark Discount Rate	'
	As of October 31, 2013, the benchmark by plan was as follows.
	Pension plan		4.55%
	NCNG SERP		3.89%
	Directors' SERP		4.09%
	Piedmont SERP		3.31%
	OPEB		4.44%
The Weighted Average Assumptions Used To Determine The Benefit Obligation and Net Periodic Benefit Cost	'
	The weighted average assumptions used in the measurement of the benefit obligation as of October 31, 2013 and 2012 are presented below.
		Qualified Pension		Nonqualified Pension		Other Benefits
		2013	2012	2013	2012	2013	2012
	Discount rate	4.55%	3.51%	3.98%	2.95%	4.44%	3.34%
	Rate of compensation increase	3.72%	3.76%	N/A	N/A	N/A	N/A
	The weighted average assumptions used to determine the net periodic benefit cost as of October 31, 2013, 2012 and 2011 are presented below.
		Qualified Pension			Nonqualified Pension
		2013	2012	2011	2013	2012	2011
	Discount rate	3.51%	4.67%	5.47%	2.95%	4.10%	4.37%
	Expected long-term rate of return on plan assets	8.00%	8.00%	8.00%	N/A	N/A	N/A
	Rate of compensation increase	3.76%	3.78%	3.87%	N/A	N/A	N/A
		Other Benefits
		2013	2012	2011
	Discount rate	3.34%	4.36%	4.85%
	Expected long-term rate of return on plan assets	8.00%	8.00%	8.00%
	Rate of compensation increase	N/A	N/A	N/A
Anticipated Employer Contribution To Benefit Plans	'
	We anticipate that we will contribute the following amounts to our plans in 2014.
	In thousands
	Qualified pension plan *	$	20,000
	Nonqualified pension plans		444
	MPP plan		885
	OPEB plan		1,500
	* Funded in November 2013.
Expected Benefit Payments For The Next Ten Years	'
	Benefit payments, which reflect expected future service, as appropriate, are expected to be paid for the next ten years ending October 31 as follows.
		Qualified			Nonqualified			Other
	In thousands	Pension			Pension			Benefits
	2014	$	25,918		$	444		$	2,140
	2015		16,918			458			2,262
	2016		15,169			434			2,322
	2017		16,154			410			2,417
	2018		18,672			383			2,507
	2019 - 2023		106,226			1,890			13,640
Assumed Health Care Cost Trend Rates	'
	The assumed health care cost trend rates used in measuring the accumulated OPEB obligation for the medical plans for all participants as of October 31, 2013 and 2012 are presented below.
		2013		2012
	Health care cost trend rate assumed for next year	7.40%		7.50%
	Rate to which the cost trend is assumed to decline (the ultimate trend rate)	5.00%		5.00%
	Year that the rate reaches the ultimate trend rate	2027		2027
Effect of One-Percentage-Point Change in Assumed Health Care Cost Trend Rates	'
	A change of 1% would have the following effects.
	In thousands			1% Increase			1% Decrease
	Effect on total of service and interest cost components of net periodic
	postretirement health care benefit cost for the year ended October 31, 2013			$	21		$	-27
	Effect on the health care cost component of the accumulated postretirement
	benefit obligation as of October 31, 2013				690			-699
Redemption Limitations, Restrictions and Notice Requirements	'
	As stated above, some of our investments for the qualified pension plan have redemption limitations, restrictions and notice requirements which are further explained below.
							Redemptions
			Redemption				Notice
	Investment		Frequency		Other Redemption Restrictions		Period
	Common trust fund -		Monthly		None		30 days
	International growth
	Common trust fund -		Daily		None		5 days
	International value
	Hedge fund of funds		Quarterly		Redeemed in whole or part but not less than the minimum redemption amount for each currency. Redemption within one year of purchase is subject to 1.5% redemption fee. Redeemed on "first in first out" basis. None of our investment is subject to the redemption fee. Fund's Board of Directors may limit or suspend share redemptions until a further notification ending suspension. No such notification has been received as of October 31, 2013.		65 days
	Private equity fund of funds		Limited		Investors have only very limited withdrawal rights for specific legal or regulatory reasons. Any transfer of interest will be subject to approval.		-1
	Commodities fund of funds		Monthly		Redemption within one year of purchase is subject to 1% redemption fee. None of our investment is subject to the redemption fee. If 95% or more of the balance is requested, 95% of the balance will be paid within 30 days. Any outstanding balance or interest owed will be paid after the annual audit is complete.		35 days
	(1) The investment cannot be redeemed. We receive distributions only through the liquidation of the underlying assets. The assets are expected to be liquidated over the next 10 to 12 years.
The Qualified Pension And The OPEB Plan's Asset Allocations By Level Within The Fair Value Hierarchy	'
	The qualified pension plan's asset allocations by level within the fair value hierarchy at October 31, 2013 and 2012 are presented below.
		Qualified Pension Plan as of October 31, 2013
					Significant
		Quoted Prices			Other			Significant
		in Active			Observable			Unobservable			Total
		Markets			Inputs			Inputs			Carrying		% of
	In thousands	(Level 1)			(Level 2)			(Level 3)			Value		Total
	Cash and cash equivalents	$	5,566		$	156		$	-		$	5,722	2%
	Fixed Income Securities:												38%
	U.S. treasuries		-			24,078			-			24,078	8%
	Long duration bonds		-			34,041			-			34,041	11%
	Corporate bonds		-			42,701			-			42,701	14%
	High yield bonds		14,680			-			-			14,680	5%
	Collateralized mortgage
	obligations		-			1,098			-			1,098	-%
	Municipals		-			-			-			-	-%
	Derivatives		6			-17			-			-11	-%
	Equity Securities:												43%
	Large cap core index		12,023			-			-			12,023	4%
	Large cap value		16,908			-			-			16,908	6%
	Large cap growth		17,823			-			-			17,823	6%
	Small cap value		30,831			-			-			30,831	10%
	Common trust fund - International
	value		-			24,460			-			24,460	8%
	Common trust fund - International
	growth		-			27,270			-			27,270	9%
	Real Estate:												5%
	Global REIT		15,042			-			-			15,042	5%
	Other Investments:												12%
	Hedge fund of funds		-			18,571			-			18,571	6%
	Private equity fund of funds		-			-			4,659			4,659	2%
	Commodities fund of funds		-			10,765			-			10,765	4%
	Total assets at fair value	$	112,879		$	183,123		$	4,659		$	300,661	100%
	Percent of fair value hierarchy		37%			61%			2%			100%
		Qualified Pension Plan as of October 31, 2012
						Significant
			Quoted Prices			Other			Significant
			in Active			Observable			Unobservable			Total
			Markets			Inputs			Inputs			Carrying	% of
	In thousands		(Level 1)			(Level 2)			(Level 3)			Value	Total
	Cash and cash equivalents	$	5,346		$	-		$	-		$	5,346	2%
	Fixed Income Securities:												45%
	U.S. treasuries		-			17,544			-			17,544	6%
	Long duration bonds		-			63,565			-			63,565	23%
	Corporate bonds		-			26,368			-			26,368	10%
	High yield bonds		13,777			-			-			13,777	5%
	Collateralized mortgage
	obligations		-			1,513			-			1,513	1%
	Municipals		-			345			-			345	-%
	Derivatives		-3			-86			-			-89	-%
	Equity Securities:												36%
	Large cap core index		10,260			-			-			10,260	4%
	Large cap value		10,427			-			-			10,427	4%
	Large cap growth		15,252			-			-			15,252	6%
	Small cap value		26,335			-			-			26,335	10%
	International value		14,376			-			-			14,376	5%
	Common trust fund - International
	growth		-			18,678			-			18,678	7%
	Real Estate:												6%
	Global REIT		16,252			-			-			16,252	6%
	Other Investments:												11%
	Hedge fund of funds		-			16,995			-			16,995	6%
	Private equity fund of funds		-			-			3,522			3,522	1%
Commodities fund of funds		-			11,871			-			11,871	4%
Total assets at fair value	$	112,022		$	156,793		$	3,522		$	272,337	100%
Percent of fair value hierarchy		41%			58%			1%			100%
	Other Benefits as of October 31, 2013
				Significant
	Quoted Prices			Other			Significant
	in Active			Observable			Unobservable			Total
	Markets			Inputs			Inputs			Carrying		% of
In thousands	(Level 1)			(Level 2)			(Level 3)			Value		Total
Cash and cash equivalents	$	982		$	-		$	-		$	982	4%
Fixed Income Securities:												46%
U.S. treasuries		2,582			-			-			2,582	10%
Corporate bonds / Other fixed
income securities		9,232			-			-			9,232	36%
Equity Securities:												45%
Large cap value		1,327			-			-			1,327	5%
Large cap growth		1,352			-			-			1,352	5%
Small cap value		1,331			-			-			1,331	5%
Small cap growth		1,313			-			-			1,313	5%
Large cap index		2,384			-			-			2,384	9%
International blend		4,206			-			-			4,206	16%
Real Estate:												5%
Global REIT		1,252			-			-			1,252	5%
Total assets at fair value	$	25,961		$	-		$	-		$	25,961	100%
Percent of fair value hierarchy		100%			-%			-%			100%
	Other Benefits as of October 31, 2012
				Significant
	Quoted Prices			Other			Significant
	in Active			Observable			Unobservable			Total
	Markets			Inputs			Inputs			Carrying		% of
In thousands	(Level 1)			(Level 2)			(Level 3)			Value		Total
Cash and cash equivalents	$	926		$	-		$	-		$	926	4%
Fixed Income Securities:												46%
U.S. treasuries		2,345			-			-			2,345	10%
Corporate bonds / Other fixed
income securities		8,474			-			-			8,474	36%
Equity Securities:												45%
Large cap value		1,221			-			-			1,221	5%
Large cap growth		1,149			-			-			1,149	5%
Small cap value		1,177			-			-			1,177	5%
Small cap growth		1,155			-			-			1,155	5%
Large cap index		2,148			-			-			2,148	9%
International blend		3,907			-			-			3,907	16%
Real Estate:												5%
Global REIT		1,161			-			-			1,161	5%
Total assets at fair value	$	23,663		$	-		$	-		$	23,663	100%
Percent of fair value hierarchy		100%			-%			-%			100%
Level 3 Qualified Pension Plan Reconciliation	'
	In 2012, we transferred amounts from Level 3 to Level 2 for our investments in the hedge fund of funds and the commodities fund of funds because inputs became more observable. The international value fund that was classified as a Level 1 asset as of October 31, 2012 was sold, and the proceeds were invested in the common trust fund – international value during fiscal year 2013. The following is a reconciliation of the assets in the qualified pension plan that are classified as Level 3 in the fair value hierarchy.
					Private
		Hedge Fund			Equity Fund			Commodities
	In thousands	of Funds			of Funds			Fund of Funds				Total
	Balance, October 31, 2011	$	6,207		$	1,925		$	8,472		$	16,604
	Actual return on plan assets:
	Relating to assets still held at the reporting date		-			13			-			13
	Relating to assets sold during the period		-			145			-			145
	Purchases, sales and settlements (net)		-			1,439			-			1,439
	Transfer in/out of Level 3		-6,207			-			-8,472			-14,679
	Balance, October 31, 2012		-			3,522			-			3,522
	Actual return on plan assets:
	Relating to assets still held at the reporting date		-			116			-			116
	Relating to assets sold during the period		-			61			-			61
	Purchases, sales and settlements (net)		-			960			-			960
	Transfer in/out of Level 3		-			-			-			-
	Balance, October 31, 2013	$	-		$	4,659		$	-		$	4,659
401(K) Matching Contributions	'
	For the years ended October 31, 2013, 2012 and 2011, we made matching contributions to participant accounts as follows.
	In thousands		2013			2012			2011
	401(k) matching contributions		$	5,688		$	5,400		$	5,203

Employee_Share_Based_Plans_Tab

Employee Share Based Plans (Tables)	12 Months Ended
	Oct. 31, 2013
Employee Share Based Plans Details [Abstract]	'
Compensation Expense And Liabilities [Table Text Block]	'
	The compensation expense related to the incentive compensation plans for the years ended October 31, 2013, 2012 and 2011, and the amounts recorded as liabilities as of October 31, 2013 and 2012 are presented below.
	In thousands		2013		2012		2011
	Compensation expense	$	4,526	$	5,730	$	2,604
	Tax benefit		1,538		2,080		673
	Liability		11,098		10,631
Expected Payout For Approved Incentive Compensation Plans [Table Text Block]	'
	Based on current accrual assumptions as of October 31, 2013, the expected payout for the approved incentive compensation awards at target will occur in the following fiscal years.
	In thousands	2014		2015		2016		2017
	Amount of payout	$	4,071	$	4,290	$	2,290	$	446

Income_Taxes_Tables

Income Taxes (Tables)	12 Months Ended
	Oct. 31, 2013
Income Taxes Disclosure [Abstract]	'
Schedule Of Components Of Income Tax Expense (Benefit) [Table Text Block]	'
	The components of income tax expense for the years ended October 31, 2013, 2012 and 2011 are presented below.
			2013						2012				2011
	In thousands		Federal			State			Federal		State		Federal		State
	Charged (Credited) to operating income:
	Current		$	-3,032		$	919		$	-29,062	$	1,857	$	-11,403	$	4,209
	Deferred			67,885			11,829			86,496		10,144		64,806		6,597
	Tax Credits:
	Utilization			-			-			-		-		184		-
	Amortization			-267			-			-334		-		-325		-
	Total			64,586			12,748			57,100		12,001		53,262		10,806
	Charged (Credited) to other income (expense):
	Current			6,049			984			5,636		1,027		3,263		-36
	Deferred			2,225			-646			2,214		239		4,167		824
	Total			8,274			338			7,850		1,266		7,430		788
	Total		$	72,860		$	13,086		$	64,950	$	13,267	$	60,692	$	11,594
Schedule Of Effective Income Tax Rate Reconciliation [Table Text Block]	'
	A reconciliation of income tax expense at the federal statutory rate to recorded income tax expense for the years ended October 31, 2013, 2012 and 2011 is presented below.
	In thousands		2013			2012			2011
	Federal taxes at 35%		$	77,127		$	69,322		$	65,049
	State income taxes, net of federal benefit			8,506			8,624			7,536
	Amortization of investment tax credits			-267			-334			-325
	Other, net			580			605			26
	Total		$	85,946		$	78,217		$	72,286
Schedule Of Deferred Tax Assets And Liabilities [Table Text Block]	'
	As of October 31, 2013 and 2012, deferred income taxes consisted of the following temporary differences.
	In thousands		2013			2012
	Deferred tax assets:
	Benefit of loss carryforwards	$	66,087		$	3,092
	Employee benefits and compensation		13,834			22,286
	Revenue requirement		19,062			10,148
	Utility plant		10,386			11,285
	Other		12,796			9,173
	Total deferred tax assets		122,165			55,984
	Valuation allowance		-505			-505
	Total deferred tax assets, net		121,660			55,479
	Deferred tax liabilities:
	Utility plant		652,822			523,232
	Revenues and cost of gas		21,257			26,816
	Equity method investments		38,710			34,092
	Deferred costs		59,221			73,744
	Other		18,324			8,348
	Total deferred tax liabilities		790,334			666,232
	Net deferred income tax liabilities	$	668,674		$	610,753
Summary Of Valuation Allowance [Table Text Block]	'
	A reconciliation of changes in the deferred tax valuation allowance for the years ended October 31, 2013, 2012 and 2011 is presented below.
	In thousands		2013			2012			2011
	Balance at beginning of year	$	505		$	505		$	1,324
	Credited to income tax expense		-			-			-819
	Balance at end of year	$	505		$	505		$	505

Equity_Method_Investments_Tabl

Equity Method Investments (Tables)	12 Months Ended
	Oct. 31, 2013
Equity Method Investments Disclosure [Abstract]	'
EquityMethodInvestmentsTextBlock	'
	For each of the years ended October 31, 2013, 2012 and 2011, these transportation costs and the amounts we owed Cardinal as of October 31, 2013 and 2012 are as follows.
	In thousands	2013			2012		2011
	Transportation costs	$	8,775		$	6,613	$	4,104
	Trade accounts payable		755			855
	Summarized financial information provided to us by Cardinal for 100% of Cardinal as of September 30, 2013 and 2012, and for the twelve months ended September 30, 2013, 2012 and 2011 is presented below.
	In thousands	2013			2012		2011
	Current assets	$	15,179		$	9,179
	Noncurrent assets		116,414			120,437
	Current liabilities		2,637			1,786
	Noncurrent liabilities		45,273			45,702
	Revenues		17,649			16,165	$	13,633
	Gross profit		17,649			16,165		13,633
	Income before income taxes		9,361			10,433		6,473
	For the years ended October 31, 2013, 2012 and 2011, these gas storage costs and the amounts we owed Pine Needle as of October 31, 2013 and 2012 are as follows.
	In thousands	2013			2012		2011
	Gas storage costs	$	11,098		$	10,410	$	10,677
	Trade accounts payable		940			914
	Summarized financial information provided to us by Pine Needle for 100% of Pine Needle as of September 30, 2013 and 2012, and for the twelve months ended September 30, 2013, 2012 and 2011 is presented below.
	In thousands	2013			2012		2011
	Current assets	$	9,225		$	11,937
	Noncurrent assets		74,710			77,463
	Current liabilities		3,531			4,278
	Noncurrent liabilities		35,391			35,851
	Revenues		16,810			16,390	$	17,666
	Gross profit		16,810			16,390		17,666
	Income before income taxes		5,804			5,832		5,763
	For the years ended October 31, 2013, 2012 and 2011, our operating revenues from these sales and the amounts SouthStar owed us as of October 31, 2013 and 2012 are as follows.
	In thousands	2013			2012		2011
	Operating revenues	$	3,291		$	2,442	$	4,961
	Trade accounts receivable		441			473
	Summarized financial information provided to us by SouthStar for 100% of SouthStar as of September 30, 2013 and 2012, and for the twelve months ended September 30, 2013, 2012 and 2011 is presented below.
	In thousands	2013			2012		2011
	Current assets	$	194,793		$	152,422
	Noncurrent assets		136,753			9,803
	Current liabilities		76,304			42,197
	Noncurrent liabilities		53			1
	Revenues		639,426			585,291	$	733,987
	Gross profit		174,993			161,122		176,010
	Income before income taxes		103,146			94,631		103,704
	For the years ended October 31, 2013, 2012 and 2011, these gas storage costs and the amounts we owed Hardy Storage as of October 31, 2013 and 2012 are as follows.
	In thousands	2013			2012		2011
	Gas storage costs	$	9,702		$	9,702	$	9,702
	Trade accounts payable		808			808
	Summarized financial information provided to us by Hardy Storage for 100% of Hardy Storage as of October 31, 2013 and 2012, and for the twelve months ended October 31, 2013, 2012 and 2011 is presented below.
	In thousands	2013			2012		2011
	Current assets	$	7,641		$	10,302
	Noncurrent assets		161,282			164,374
	Current liabilities		12,378			14,534
	Noncurrent liabilities		87,184			95,061
	Revenues		24,375			24,359	$	24,378
	Gross profit		24,375			24,359		24,378
	Income before income taxes		10,582			9,939		9,657
	Summarized financial information provided to us by Constitution for 100% of Constitution as of September 30, 2013, and for the twelve months ended September 30, 2013 is presented below.
	In thousands	2013		-1
	Current assets	$	10,944
	Noncurrent assets		62,438
	Current liabilities		7,960
	Noncurrent liabilities		-
	Revenues		-
	Gross profit		-
	Income before income taxes		3,459
	(1) Presented is the period in which we have a membership interest in Constitution, and not prior periods when we had no membership interest in Constitution. Our membership in Constitution began in November 2012.

Variable_Interest_Entities_Tab

Variable Interest Entities (Tables)	12 Months Ended
	Oct. 31, 2013
Variable Interest Entities Tables [Abstract]	'
Schedule Of Variable Interest Entities Investment Balances [Table Text Block]	'
	As of October 31, 2013 and 2012, our investment balances are as follows.
			October 31,		October 31,
	In thousands		2013		2012
	Cardinal	$	18,207	$	17,969
	Pine Needle		20,270		19,239
	SouthStar		38,372		18,118
	Hardy Storage		34,681		32,541
	Constitution		16,939		-
	Total equity method investments in non-utility activities	$	128,469	$	87,867

Business_Segments_Tables

Business Segments (Tables)	12 Months Ended
	Oct. 31, 2013
Business Segments Disclosure [Abstract]	'
Schedule of Segment Reporting Information, by Segment [Table Text Block]	'
	Operations by segment for the years ended October 31, 2013, 2012 and 2011, and as of October 31, 2013, 2012 and 2011 are presented below.
		Regulated		Non-Utility
	In thousands	Utility		Activities		Total
	2013
	Revenues from external customers	$	1,278,229	$	-	$	1,278,229
	Margin		621,490		-		621,490
	Operations and maintenance expenses		253,120		181		253,301
	Depreciation		112,207		18		112,225
	Income from equity method investments		-		26,056		26,056
	Interest expense		24,938		-		24,938
	Operating income (loss) before income taxes		221,528		-352		221,176
	Income before income taxes		194,659		25,704		220,363
	Total assets		4,053,591		128,832		4,182,423
	Equity method investments in non-utility activities		-		128,469		128,469
	Construction expenditures		599,999		-		599,999
		Regulated		Non-Utility
	In thousands	Utility		Activities		Total
	2012
	Revenues from external customers	$	1,122,780	$	-	$	1,122,780
	Margin		575,446		-		575,446
	Operations and maintenance expenses		242,599		102		242,701
	Depreciation		103,192		18		103,210
	Income from equity method investments		-		23,904		23,904
	Interest expense		20,097		-		20,097
	Operating income (loss) before income taxes		194,824		-264		194,560
	Income before income taxes		174,424		23,640		198,064
	Total assets		3,475,640		88,247		3,563,887
	Equity method investments in non-utility activities		-		87,867		87,867
	Construction expenditures		529,576		-		529,576
		Regulated		Non-Utility
	In thousands	Utility		Activities		Total
	2011
	Revenues from external customers	$	1,433,905	$	-	$	1,433,905
	Margin		573,639		-		573,639
	Operations and maintenance expenses		225,351		109		225,460
	Depreciation		102,829		28		102,857
	Income from equity method investments		-		24,027		24,027
	Interest expense		43,992		-		43,992
	Operating income (loss) before income taxes		207,079		-120		206,959
	Income before income taxes		161,925		23,929		185,854
	Total assets		2,968,574		85,519		3,054,093
	Equity method investments in non-utility activities		-		85,121		85,121
	Construction expenditures		243,641		-		243,641
Reconciliation of Operating Profit (Loss) from Segments to Consolidated [Table Text Block]	'
	Reconciliations to the consolidated financial statements for the years ended October 31, 2013, 2012 and 2011, and as of October 31, 2013 and 2012 are as follows.
	In thousands	2013		2012		2011
	Operating Income:
	Segment operating income before income taxes	$	221,176	$	194,560	$	206,959
	Utility income taxes		-77,334		-69,101		-64,068
	Non-utility activities operating loss before income taxes		352		264		120
	Total	$	144,194	$	125,723	$	143,011
Reconciliation of income before taxes to net income	'
	Reconciliations to the consolidated financial statements for the years ended October 31, 2013, 2012 and 2011, and as of October 31, 2013 and 2012 are as follows.
	Net Income:
	Income before income taxes for reportable segments	$	220,363	$	198,064	$	185,854
	Income taxes		-85,946		-78,217		-72,286
	Total	$	134,417	$	119,847	$	113,568
Reconciliation of Assets from Segment to Consolidated [Table Text Block]	'
	Reconciliations to the consolidated financial statements for the years ended October 31, 2013, 2012 and 2011, and as of October 31, 2013 and 2012 are as follows.
	In thousands	2013		2012
	Consolidated Assets:
	Total assets for reportable segments	$	4,182,423	$	3,563,887
	Eliminations/Adjustments		186,186		206,052
	Total	$	4,368,609	$	3,769,939

Selected_Quarterly_Financial_D1

Selected Quarterly Financial Data (Tables)	12 Months Ended
	Oct. 31, 2013
Quarterly Financial Data [Abstract]	'
Schedule of Quarterly Financial Information [Table Text Block]	'
	16. Selected Quarterly Financial Data (In thousands except per share amounts) (Unaudited)
										Earnings (Loss)
						Operating		Net		Per Share of
		Operating				Income		Income		Common Stock
		Revenues		Margin		(Loss)		(Loss)		Basic		Diluted
	Fiscal Year 2013
	31-Jan	$	515,875	$	231,623	$	86,213	$	85,923	$	1.19	$	1.18
	30-Apr		399,411		183,856		51,504		55,790		0.74		0.74
	31-Jul		162,943		97,000		591		-2,293		-0.03		-0.03
	31-Oct		200,000		109,011		5,886		-5,003		-0.07		-0.07
	Fiscal Year 2012
	31-Jan	$	471,840	$	220,237	$	79,819	$	76,227	$	1.06	$	1.05
	30-Apr		308,432		171,951		48,782		50,192		0.7		0.7
	31-Jul		161,123		86,460		-2,513		-4,613		-0.06		-0.06
	31-Oct		181,385		96,798		-365		-1,959		-0.03		-0.03

Summary_Of_Significant_Account2

Summary Of Significant Accounting Policies (Details) (USD $)

12 Months Ended

180 Months Ended

0 Months Ended

60 Months Ended

82 Months Ended

60 Months Ended

38 Months Ended

12 Months Ended

Oct. 31, 2013

Oct. 31, 2012

Oct. 31, 2011

Oct. 31, 2018

Oct. 31, 2012

Oct. 31, 2012

Oct. 31, 2013

Oct. 31, 2012

Oct. 31, 2013

Oct. 31, 2012

Oct. 31, 2013

Oct. 31, 2012

Oct. 31, 2013

Oct. 31, 2012

Oct. 31, 2013

Oct. 31, 2012

Oct. 31, 2013

Oct. 31, 2012

Oct. 31, 2013

Oct. 31, 2012

Oct. 31, 2013

Oct. 31, 2012

Oct. 31, 2013

Oct. 31, 2012

Aug. 31, 2013

Dec. 31, 2018

Dec. 31, 2013

Oct. 31, 2013

Oct. 31, 2012

Oct. 31, 2020

Dec. 31, 2013

Oct. 31, 2013

Oct. 31, 2012

Oct. 31, 2013

Oct. 31, 2012

Dec. 31, 2018

Oct. 31, 2013

Aug. 31, 2013

Oct. 31, 2013

Oct. 31, 2012

Oct. 31, 2013

Oct. 31, 2012

Oct. 31, 2013

Oct. 31, 2012

Oct. 31, 2013

Oct. 31, 2012

Dec. 31, 2013

Feb. 28, 2017

Oct. 31, 2013

Oct. 31, 2013

Oct. 31, 2013

Oct. 31, 2012

Oct. 31, 2013

Oct. 31, 2013

Oct. 31, 2013

Land Costs [Member]

Non-real Estate Costs [Member]

Money Market Funds Member

Money Market Funds Member

Equity Funds Member

Equity Funds Member

Asset Retirement Obligation Costs [Member]

Asset Retirement Obligation Costs [Member]

Amount Due To Customers

Amount Due To Customers

Deferred Income Taxes

Deferred Income Taxes

Amounts Not Yet Recognized As Component Of Pension and Other Post Retirement Benefit Costs

Amounts Not Yet Recognized As Component Of Pension and Other Post Retirement Benefit Costs

Unamortized Debt Expense

Unamortized Debt Expense

Amounts Due From Customers

Amounts Due From Customers

Environmental Restoration Costs [Member]

Environmental Restoration Costs [Member]

Environmental Restoration Costs [Member]

Environmental Restoration Costs [Member]

Environmental Restoration Costs [Member]

Deferred Operations And Maintenance Expenses

Deferred Operations And Maintenance Expenses

Deferred Operations And Maintenance Expenses

Deferred Operations And Maintenance Expenses

Deferred Operations And Maintenance Expenses

Deferred Operations And Maintenance Expenses

Deferred Pipeline Integrity Expenses

Deferred Pipeline Integrity Expenses

Deferred Pipeline Integrity Expenses

Deferred Pipeline Integrity Expenses

Deferred Pipeline Integrity Expenses

Deferred Pension and Other Retirement Benefits Costs

Deferred Pension and Other Retirement Benefits Costs

Amounts Not Yet Recognized As Component Of Pension and Other Post Retirement Benefit Costs

Amounts Not Yet Recognized As Component Of Pension and Other Post Retirement Benefit Costs

Asset Retirement Obligation Costs [Member]

Asset Retirement Obligation Costs [Member]

Robeson LNG Development Cost [Member]

Robeson LNG Development Cost [Member]

Robeson LNG Development Cost [Member]

Robeson LNG Development Cost [Member]

Robeson LNG Development Cost [Member]

Robeson LNG Development Cost [Member]

Other

Other

Unrealized Mark To Market [Member]

Maximum [Member]

Minimum [Member]

NCUC [Member]

NCUC [Member]

NCUC [Member]

NCUC [Member]

NCUC [Member]

NCUC [Member]

NCUC [Member]

NCUC [Member]

NCUC [Member]

NCUC [Member]

NCUC [Member]

NCUC [Member]

NCUC [Member]

PSCSC [Member]

General Rate Application Settlement 2013 [Member]

General Rate Application Settlement 2013 [Member]

General Rate Application Settlement 2013 [Member]

General Rate Application Settlement 2013 [Member]

General Rate Application Settlement 2013 [Member]

Asset Retirement Obligations [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Regulatory Non Legal Asset Removal Obligations

$493,111,000

$464,334,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Conditional cost of removal obligations

27,016,000

28,629,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cost of removal obligations

520,127,000

492,963,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Asset Retirement Obligation Roll Forward Analysis Roll Forward

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Beginning Of Period

28,629,000

27,395,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Liabilities Incurred During The Period

2,052,000

1,705,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Liabilities Settled During The Period

-2,389,000

-2,038,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Accretion

1,641,000

1,570,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Adjustment To Estimated Cash Flows *

-2,917,000

-3,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

End Of Period

27,016,000

28,629,000

27,395,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Credit Adjusted Risk Free Rate

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

5.87%

4.61%

Weighted Average Risk Free Rate

5.73%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Defined Benefit Pension Plans and Defined Benefit Postretirement Plans Disclosure [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Near Term Redemption

'180 days

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Goodwill [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Goodwill, Impairment Loss

0

0

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Inventory Net Abstract

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Natural Gas Inventories Not Available For Sale Held by Asset Manager

31,500,000

26,700,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Movement in Valuation Allowances and Reserves [Roll Forward]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Allowance For Doubtful Accounts Balance At Beginning Of Year

1,579,000

1,347,000

929,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Allowance For Doubtful Accounts Charged To Uncollectible Expense

5,314,000

4,584,000

4,842,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Allowance For Doubtful Accounts Written Off Net Of Recoveries

-5,289,000

-4,352,000

-4,424,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Allowance For Doubtful Accounts Balance At End Of Year

1,604,000

1,579,000

1,347,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Property Plant And Equipment [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Property Plant And Equipment Useful Life

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'88 years

'4 years

Depreciation Study Requirement

'In North Carolina, we are required to conduct a depreciation study every five years and file the results with the regulatory commission. No such five-year requirement exists in South Carolina or Tennessee; however, we periodically propose revised rates in those states based on depreciation studies.

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Weighted Average Depreciation Rate

2.77%

2.94%

3.19%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Allowance for borrowed funds used during construction

30,975,000

25,211,000

8,619,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Regulatory Assets [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Regulatory Assets

246,306,000

293,104,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

15,423,000

13,583,000

66,321,000

81,626,000

9,416,000

10,202,000

'

'

6,300,000

6,376,000

7,050,000

'

6,300,000

6,376,000

7,050,000

19,449,000

13,691,000

'

19,449,000

17,300,000

20,736,000

20,139,000

80,604,000

123,290,000

22,974,000

21,129,000

1,808,000

0

1,200,000

'

1,200,000

500,000

3,199,000

2,394,000

'

'

'

Amortization Time Period For Specified Expenses

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'5 years

'5 years

'

'

'

'82 months

'

'

'

'

'

'5 years

'

'

'

'

'

'

'

'

'

'

'

'38 months

'

'

'

'

'

'

'

Regulatory Assets On Which No Return Is Earned During Recovery Period

400,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Remaining Recovery Period Of Regulatory Assets For Which No Return On Investment During Recovery Period Is Provided

'

'

'

'15 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Amount Of Regulatory Costs Approved To Be Accrued Not Included In Rate Base

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

7,900,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

80,600,000

'

23,000,000

'

'

'

'

'

'

'

'

'

'

'

'

Unrealized Mark To Market Amounts On Which No Return Is Earned On Until Recorded

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,900,000

'

'

Regulatory Liabilities [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Regulatory Liabilities

541,897,000

489,692,000

'

'

'

'

'

'

'

'

493,111,000

464,334,000

0

28,000

48,647,000

25,330,000

139,000

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Investment Measurement [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Current trading securities (cost)

134,000

134,000

'

'

'

'

0

0

134,000

134,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Noncurrent trading securities(cost)

2,375,000

1,911,000

'

'

'

'

380,000

243,000

1,995,000

1,668,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Current trading securities

199,000

157,000

'

'

'

'

0

0

199,000

157,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Noncurrent trading securities

2,995,000

2,131,000

'

'

'

'

380,000

243,000

2,615,000

1,888,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total trading securities

3,194,000

2,288,000

'

'

'

'

380,000

243,000

2,814,000

2,045,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total trading securities (cost)

2,509,000

2,045,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Trade Accounts Receivable And Allowance For Doubtful Accounts [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Gas Receivables

78,540,000

55,956,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Merchandise And Jobbing Receivables

2,274,000

2,323,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Allowance For Doubtful Accounts

-1,604,000

-1,579,000

-1,347,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Trade accounts receivable

79,210,000

56,700,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Customers Payment Due Date

'30 days

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Unamortized Debt Expense [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Long Term Debt Expense Amortization Period

'5 to 30 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Short Term Debt Expense Amortization Period

'5 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Utility Plant [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Plant held for future use

3,155,000

6,743,000

'

'

3,200,000

3,500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Intangible Plant

3,374,000

3,374,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Other Storage Plant

171,349,000

118,277,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Transmission Plant

1,403,829,000

866,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Distribution Plant

2,505,160,000

2,422,988,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

General Plant

335,847,000

329,867,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Asset Retirement Cost

7,565,000

10,819,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Contribution In Aid Of Construction

-5,187,000

-5,147,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Utility Plant In Service

4,421,937,000

3,746,178,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Less Accumulated Depreciation

-1,088,331,000

-1,036,814,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Utility Plant In Service, Net

3,333,606,000

2,709,364,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Construction work in progress

297,717,000

388,979,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total Utility Plant, Net

3,634,478,000

3,105,086,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Write-off of Plant

$1,800,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Regulatory_Matters_Details

Regulatory Matters (Details) (USD $)

12 Months Ended

1 Months Ended

12 Months Ended

24 Months Ended

132 Months Ended

3 Months Ended

12 Months Ended

60 Months Ended

12 Months Ended

82 Months Ended

106 Months Ended

132 Months Ended

144 Months Ended

180 Months Ended

144 Months Ended

0 Months Ended

60 Months Ended

38 Months Ended

12 Months Ended

18 Months Ended

1 Months Ended

0 Months Ended

96 Months Ended

0 Months Ended

1 Months Ended

12 Months Ended

1 Months Ended

96 Months Ended

Oct. 31, 2013

Oct. 31, 2012

Oct. 31, 2011

Oct. 31, 2013

Oct. 31, 2012

Oct. 31, 2013

Oct. 31, 2012

Oct. 31, 2013

Oct. 31, 2012

Oct. 31, 2013

Oct. 31, 2012

31-May-13

Oct. 31, 2013

Oct. 31, 2012

Dec. 31, 2014

Oct. 31, 2013

Oct. 31, 2013

Oct. 31, 2013

Dec. 31, 2001

Dec. 31, 2000

Dec. 31, 2001

Dec. 31, 2008

Jun. 30, 2005

31-May-10

31-May-11

31-May-12

31-May-13

Dec. 31, 2013

Dec. 31, 2014

Dec. 31, 2014

Dec. 31, 2014

Dec. 31, 2014

Dec. 31, 2014

Dec. 31, 2018

Oct. 31, 2013

Aug. 31, 2013

31-May-11

Jun. 30, 2008

Oct. 31, 2020

Oct. 31, 2008

Dec. 31, 2008

Oct. 31, 2020

Dec. 31, 2013

Oct. 31, 2013

Oct. 31, 2012

Oct. 31, 2020

Oct. 31, 2020

Oct. 31, 2008

Aug. 31, 2013

Dec. 31, 2018

Dec. 31, 2013

Dec. 31, 2013

Feb. 28, 2017

Oct. 31, 2013

Oct. 31, 2013

Oct. 31, 2013

Oct. 31, 2013

Oct. 31, 2012

Oct. 31, 2012

Oct. 31, 2012

Oct. 31, 2013

Oct. 31, 2013

Oct. 31, 2014

Oct. 31, 2014

Oct. 31, 2014

Dec. 31, 2013

Oct. 31, 2013

Jun. 30, 2010

Oct. 31, 2013

Feb. 29, 2012

31-May-12

Oct. 31, 2011

Mar. 01, 2012

Feb. 29, 2020

Oct. 31, 2010

Mar. 01, 2012

Sep. 30, 2011

Oct. 31, 2013

Aug. 31, 2013

Feb. 28, 2010

Oct. 31, 2011

Feb. 29, 2020

Mar. 31, 2012

Deferred Pipeline Integrity Expenses [Member]

Deferred Pipeline Integrity Expenses [Member]

Deferred Operations And Maintenance Expenses [Member]

Deferred Operations And Maintenance Expenses [Member]

Environmental Restoration Costs [Member]

Environmental Restoration Costs [Member]

Robeson LNG Development Cost [Member]

Robeson LNG Development Cost [Member]

NCUC [Member]

NCUC [Member]

NCUC [Member]

NCUC [Member]

NCUC [Member]

NCUC [Member]

NCUC [Member]

NCUC [Member]

NCUC [Member]

NCUC [Member]

NCUC [Member]

NCUC [Member]

NCUC [Member]

NCUC [Member]

NCUC [Member]

NCUC [Member]

NCUC [Member]

NCUC [Member]

NCUC [Member]

NCUC [Member]

NCUC [Member]

NCUC [Member]

NCUC [Member]

NCUC [Member]

NCUC [Member]

NCUC [Member]

NCUC [Member]

NCUC [Member]

NCUC [Member]

NCUC [Member]

NCUC [Member]

NCUC [Member]

NCUC [Member]

NCUC [Member]

NCUC [Member]

NCUC [Member]

NCUC [Member]

NCUC [Member]

NCUC [Member]

NCUC [Member]

NCUC [Member]

NCUC [Member]

NCUC [Member]

PSCSC [Member]

PSCSC [Member]

PSCSC [Member]

PSCSC [Member]

PSCSC [Member]

PSCSC [Member]

PSCSC [Member]

PSCSC [Member]

PSCSC [Member]

PSCSC [Member]

PSCSC [Member]

PSCSC [Member]

PSCSC [Member]

Tennessee Regulatory Authority [Member]

Tennessee Regulatory Authority [Member]

Tennessee Regulatory Authority [Member]

Tennessee Regulatory Authority [Member]

Tennessee Regulatory Authority [Member]

Tennessee Regulatory Authority [Member]

Tennessee Regulatory Authority [Member]

Tennessee Regulatory Authority [Member]

Tennessee Regulatory Authority [Member]

Tennessee Regulatory Authority [Member]

Tennessee Regulatory Authority [Member]

Tennessee Regulatory Authority [Member]

Tennessee Regulatory Authority [Member]

Tennessee Regulatory Authority [Member]

Tennessee Regulatory Authority [Member]

Tennessee Regulatory Authority [Member]

Revenue [Member]

Minimum [Member]

Maximum [Member]

EasternNC Exclusive Franchise Rights [Member]

EasternNC Exclusive Franchise Rights [Member]

EasternNC Exclusive Franchise Rights [Member]

EasternNC Exclusive Franchise Rights [Member]

EasternNC Exclusive Franchise Rights [Member]

General Rate Case Proceeding 2005 [Member]

North Carolina Public Staff Audit 2010 Gas Cost Review Period [Member]

North Carolina Public Staff Audit 2011 Gas Cost Review Period [Member]

North Carolina Public Staff Audit 2012 Gas Cost Review Period [Member]

North Carolina Public Staff Audit 2013 Gas Cost Review Period [Member]

General Rate Application Settlement 2013 [Member]

General Rate Application Settlement 2013 [Member]

General Rate Application Settlement 2013 [Member]

General Rate Application Settlement 2013 [Member]

General Rate Application Settlement 2013 [Member]

General Rate Application Settlement 2013 [Member]

Deferred Pipeline Integrity Expenses [Member]

Deferred Pipeline Integrity Expenses [Member]

Deferred Pipeline Integrity Expenses [Member]

Deferred Pipeline Integrity Expenses [Member]

Deferred Pipeline Integrity Expenses [Member]

Deferred Operations And Maintenance Expenses [Member]

Deferred Operations And Maintenance Expenses [Member]

Deferred Operations And Maintenance Expenses [Member]

Deferred Operations And Maintenance Expenses [Member]

Deferred Operations And Maintenance Expenses [Member]

Deferred Operations And Maintenance Expenses [Member]

Deferred Operations And Maintenance Expenses [Member]

Deferred Operations And Maintenance Expenses [Member]

Deferred Operations And Maintenance Expenses [Member]

Deferred Operations And Maintenance Expenses [Member]

Environmental Restoration Costs [Member]

Environmental Restoration Costs [Member]

Environmental Restoration Costs [Member]

Robeson LNG Development Cost [Member]

Robeson LNG Development Cost [Member]

Robeson LNG Development Cost [Member]

Minimum [Member]

Maximum [Member]

North Carolina Public Staff Audit 2011 Gas Cost Review Period [Member]

Settlement With Office Of Regulatory Staff October 2011 [Member]

Settlement With Office Of Regulatory Staff October 2011 [Member]

Settlement With Office Of Regulatory Staff October 2012 [Member]

Settlement With Office Of Regulatory Staff October 2012 [Member]

Settlement With Office Of Regulatory Staff October 2013 [Member]

Settlement With Office Of Regulatory Staff October 2013 [Member]

Environmental Restoration Costs [Member]

Environmental Restoration Costs [Member]

Robeson LNG Development Cost [Member]

Collection Nashville Franchise Fee [Member]

Collection Nashville Franchise Fee [Member]

General Rate Application Settlement 2012 [Member]

General Rate Application Settlement 2012 [Member]

General Rate Application Settlement 2012 [Member]

General Rate Application Settlement 2012 [Member]

General Rate Application Settlement 2012 [Member]

General Rate Application Settlement 2012 [Member]

Requested Adjustment Filed August 2013 [Member]

Franchise Fees [Member]

Franchise Fees [Member]

Environmental Restoration Costs [Member]

Environmental Restoration Costs [Member]

Revenue [Member]

Revenue [Member]

Revenue [Member]

Operating Expense [Member]

Revised Pre-Tax Income [Member]

General Rate Case Proceeding 2008 [Member]

General Rate Case Proceeding 2008 [Member]

General Rate Case Proceeding 2005 [Member]

General Rate Case Proceeding 2008 [Member]

General Rate Case Proceeding 2008 [Member]

General Rate Application Settlement 2013 [Member]

General Rate Application Settlement 2013 [Member]

General Rate Application Settlement 2013 [Member]

General Rate Application Settlement 2013 [Member]

General Rate Application Settlement 2013 [Member]

Margin [Member]

Operating Expense [Member]

Margin [Member]

Margin [Member]

Settlement With Office Of Regulatory Staff October 2013 [Member]

Settlement With Office Of Regulatory Staff October 2013 [Member]

Revenue [Member]

Revenue [Member]

Revenue [Member]

Collection Nashville Franchise Fee [Member]

Collection Nashville Franchise Fee [Member]

General Rate Application Settlement 2012 [Member]

General Rate Application Settlement 2012 [Member]

Gas Utility Margin [Member]

Fixed Gas Costs [Member]

Public Utilities Rate Matters Approved [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Public Utilities Approved Rate Increase (Decrease) Amount

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$30,700,000

$16,800,000

$13,800,000

($10,900,000)

$24,200,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

($3,100,000)

($1,900,000)

'

($1,100,000)

'

($100,000)

'

'

'

'

'

'

'

'

'

'

'

$11,900,000

'

'

'

'

'

'

'

Public Utilities Approved Rate Increase (Decrease) Percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3.58%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

6.30%

'

'

'

'

'

'

'

Public Utilities Approved Return On Equity Percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

10.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

11.30%

'

'

11.30%

'

11.30%

'

'

'

'

'

'

'

'

'

10.20%

'

'

'

'

'

'

'

'

'

'

Public Utilities, Approved Equity Capital Structure, Percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

50.70%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Approved Annual Average Revenue Percentage Increase From Last Rate Case

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.70%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Denied Franchise Fees

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,500,000

'

'

Operations And Maintenence Expense Maximum Deferral

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

15,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Deferral Time Period Of Operation And Maintenance Expense

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'8 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Amortization Time Period For Specified Expenses

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'5 years

'

'

'3 years

'

'82 months

'

'

'

'

'

'

'15 years

'12 years

'

'5 years

'5 years

'

'

'38 months

'

'

'

'

'

'

'

'

'

'1 year

'

'1 year

'

'

'

'

'

'

'

'

'8 years

'

'

'

'

'

'

'

'8 years

'

Overall Rate Base With Approved Rates And Charges

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,800,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Public Utilities Rate Matters Requested [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Public Utilities Requested Rate Increase (Decrease) Amount

'

'

'

'

'

'

'

'

'

'

'

79,800,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

16,700,000

'

13,100,000

2,900,000

'

'

'

Public Utilities Requested Rate Increase (Decrease) Percentage

'

'

'

'

'

'

'

'

'

'

'

9.30%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

8.90%

'

'

'

'

'

Request Transfer Plant Held For Future Use To Deferred Regulatory Asset

'

'

'

'

'

'

'

'

'

'

'

'

'

6,700,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Requested Adjustment Deferred Gas Costs

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3,700,000

'

'

'

'

Regulatory Assets

246,306,000

293,104,000

'

19,449,000

13,691,000

6,376,000

7,050,000

9,416,000

10,202,000

1,808,000

0

'

'

'

'

'

'

'

'

'

'

'

7,900,000

'

'

'

'

'

'

'

'

'

'

'

19,449,000

17,300,000

'

4,600,000

'

'

'

'

6,300,000

6,376,000

7,050,000

'

'

9,000,000

'

'

6,300,000

1,200,000

'

1,200,000

'

'

'

'

'

'

'

'

'

'

200,000

200,000

500,000

'

'

'

'

'

'

'

1,000,000

'

'

'

'

'

'

'

2,000,000

Public Utilities Description Of Regulatory Scope

'Our utility operations are regulated by the NCUC, PSCSC and TRA as to rates, service area, adequacy of service, safety standards, extensions and abandonment of facilities, accounting and depreciation. We are also regulated by the NCUC as to the issuance of long-term debt and equity securities. The NCUC and the PSCSC regulate our gas purchasing practices under a standard of prudence and audit our gas cost accounting practices. The TRA regulates our gas purchasing practices under a gas supply incentive program which compares our actual costs to market pricing benchmarks. As part of this jurisdictional oversight, all three regulatory commissions address our gas supply hedging activities. Additionally, all three regulatory commissions allow for recovery of uncollectible gas costs through the PGA. The portion of uncollectibles related to gas costs is recovered through the deferred account and only the non-gas costs, or margin, portion of uncollectibles is included in base rates and uncollectibles expense. Our three regulatory commissions have authorized us to utilize deferral accounting in connection with environmental costs.

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Maximum Utility Rate Of Return Change Under RSA

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

50

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Target Percentage Range Normalized Sales

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'22.5%

'45.0%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'22.5%

'45.0%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

North Carolina General Assembly Bond Issuance Amount

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

149,600,000

38,700,000

188,300,000

200,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Operational Feasibility Assessment Time Period

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'2 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Interest Accrued On Deferred Expenses

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

6.55%

8.69%

'

7.84%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Percentage Of Allowed Recovery For Gas Costs

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

100.00%

100.00%

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Percentage Of Net Secondary Market Margins Flowed Through To Customers

'

'

'

'

'

'

'

'

'

'

'

'

75.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

75.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

75.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Percentage Of Net Secondary Market Margins Retained

'

'

'

'

'

'

'

'

'

'

'

'

25.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

25.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

25.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Annual Incentive Cap On Gains And Losses

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,600,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Operations and maintenance

253,120,000

242,599,000

225,351,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

500,000

1,500,000

'

'

'

'

'

'

'

'

'

'

'

Audit Period To Synchronize Audit Year

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'18 months

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total Amount Of Margin Generated From Secondary Market Activity

35,900,000

38,700,000

56,100,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Amount Of Net Secondary Market Margins Flowed Through To Jurisdictional Customers

26,900,000

29,000,000

42,100,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Amount Of Net Secondary Market Margins Retained

$9,000,000

$9,700,000

$14,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Recovery Of Fixed Charges Cost Allocations

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

29.00%

'

'

37.00%

'

'

'

'

'

'

'

'

'

'

Recovery Of Volumetric Charges Cost Allocations

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

71.00%

'

'

63.00%

'

'

'

'

'

'

'

'

'

'

Earnings_Per_Share_Details

Earnings Per Share (Details) (USD $)	3 Months Ended								12 Months Ended
	Oct. 31, 2013	Jul. 31, 2013	Apr. 30, 2013	Jan. 31, 2013	Oct. 31, 2012	Jul. 31, 2012	Apr. 30, 2012	Jan. 31, 2012	Oct. 31, 2013	Oct. 31, 2012	Oct. 31, 2011
Earnings Per Share Reconciliation Of Basic And Diluted	'	'	'	'	'	'	'	'	'	'	'
Net Income	($5,003,000)	($2,293,000)	$55,790,000	$85,923,000	($1,959,000)	($4,613,000)	$50,192,000	$76,227,000	$134,417,000	$119,847,000	$113,568,000
Average shares of common stock outstanding for basic earnings per share	'	'	'	'	'	'	'	'	74,884,000	71,977,000	72,056,000
Contingently issuable shares under incentive compensation plans	'	'	'	'	'	'	'	'	289,000	301,000	210,000
Contingently issuable shares under forward sale agreements	'	'	'	'	'	'	'	'	160,000	0	0
Average shares of dilutive stock	'	'	'	'	'	'	'	'	75,333,000	72,278,000	72,266,000
Earnings Per Share of Common Stock	'	'	'	'	'	'	'	'	'	'	'
Basic EPS	($0.07)	($0.03)	$0.74	$1.19	($0.03)	($0.06)	$0.70	$1.06	$1.80	$1.67	$1.58
Diluted EPS	($0.07)	($0.03)	$0.74	$1.18	($0.03)	($0.06)	$0.70	$1.05	$1.78	$1.66	$1.57

Long_Term_Debt_Details

Long Term Debt (Details) (USD $)

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

Oct. 31, 2013

Oct. 31, 2012

Oct. 31, 2013

Oct. 31, 2013

Oct. 31, 2012

Oct. 31, 2013

Oct. 31, 2013

Oct. 31, 2012

Oct. 31, 2013

Oct. 31, 2013

Oct. 31, 2012

Oct. 31, 2013

Jul. 16, 2012

Oct. 31, 2013

Oct. 31, 2012

Oct. 31, 2013

Oct. 15, 2012

Oct. 31, 2013

Oct. 31, 2012

Aug. 02, 2013

Oct. 31, 2013

Oct. 31, 2013

Oct. 31, 2013

Oct. 31, 2013

Oct. 31, 2012

Oct. 31, 2013

Oct. 31, 2013

Oct. 31, 2012

Oct. 31, 2013

Oct. 31, 2013

Oct. 31, 2012

Oct. 31, 2013

Oct. 31, 2013

Oct. 31, 2012

Oct. 31, 2013

Oct. 31, 2013

Oct. 31, 2012

Oct. 31, 2013

Oct. 31, 2013

Oct. 31, 2012

Oct. 31, 2013

Oct. 31, 2013

Oct. 31, 2012

Oct. 31, 2013

Oct. 31, 2013

Oct. 31, 2012

Senior Notes 2.92% [Member]

Senior Notes 2.92% [Member]

Senior Notes 2.92% [Member]

Senior Notes 8.51% [Member]

Senior Notes 8.51% [Member]

Senior Notes 8.51% [Member]

Senior Notes 4.24% [Member]

Senior Notes 4.24% [Member]

Senior Notes 4.24% [Member]

Senior Notes 3.47% [Member]

Senior Notes 3.47% [Member]

Senior Notes 3.47% [Member]

Senior Notes 3.47% [Member]

Senior Notes 3.57% [Member]

Senior Notes 3.57% [Member]

Senior Notes 3.57% [Member]

Senior Notes 3.57% [Member]

Senior Notes 4.65% [Member]

Senior Notes 4.65% [Member]

Senior Notes 4.65% [Member]

Senior Notes 4.65% [Member]

Senior Notes 4.65% [Member]

Senior Notes 4.65% [Member]

Medium Term Notes 5.00% [Member]

Medium Term Notes 5.00% [Member]

Medium Term Notes 5.00% [Member]

Medium Term Notes 6.87% [Member]

Medium Term Notes 6.87% [Member]

Medium Term Notes 6.87% [Member]

Medium Term Notes 8.45% [Member]

Medium Term Notes 8.45% [Member]

Medium Term Notes 8.45% [Member]

Medium Term Notes 7.40% [Member]

Medium Term Notes 7.40% [Member]

Medium Term Notes 7.40% [Member]

Medium Term Notes 7.50% [Member]

Medium Term Notes 7.50% [Member]

Medium Term Notes 7.50% [Member]

Medium Term Notes 7.95% [Member]

Medium Term Notes 7.95% [Member]

Medium Term Notes 7.95% [Member]

Medium Term Notes 6.00% [Member]

Medium Term Notes 6.00% [Member]

Medium Term Notes 6.00% [Member]

Unsecured Debt [Member]

Unsecured Debt [Member]

Unsecured Debt [Member]

Unsecured Debt [Member]

Unsecured Debt [Member]

Unsecured Debt [Member]

Unsecured Debt [Member]

Unsecured Debt [Member]

Unsecured Debt [Member]

Unsecured Debt [Member]

Debt Instrument Redemption Period One [Member]

Debt Instrument Redemption Period Two [Member]

Unsecured Debt [Member]

Unsecured Debt [Member]

Unsecured Debt [Member]

Unsecured Debt [Member]

Unsecured Debt [Member]

Unsecured Debt [Member]

Unsecured Debt [Member]

Unsecured Debt [Member]

Unsecured Debt [Member]

Unsecured Debt [Member]

Unsecured Debt [Member]

Unsecured Debt [Member]

Unsecured Debt [Member]

Unsecured Debt [Member]

Unsecured Debt [Member]

Unsecured Debt [Member]

Debt Instrument [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Long-term debt

$1,275,000,000

$975,000,000

'

$40,000,000

$40,000,000

'

$35,000,000

$35,000,000

'

$160,000,000

$160,000,000

'

'

$100,000,000

$100,000,000

'

'

$200,000,000

$200,000,000

'

'

'

'

$300,000,000

$0

'

$100,000,000

$100,000,000

'

$45,000,000

$45,000,000

'

$40,000,000

$40,000,000

'

$55,000,000

$55,000,000

'

$40,000,000

$40,000,000

'

$60,000,000

$60,000,000

'

$100,000,000

$100,000,000

Current maturities of long-term debt

100,000,000

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Unamortized discount

143,000

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

144,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Long-term debt

1,174,857,000

975,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument Interest Rate Stated Percentage

'

'

2.92%

'

'

8.51%

'

'

4.24%

'

'

3.47%

'

'

'

3.57%

'

'

'

'

4.65%

'

'

'

'

5.00%

'

'

6.87%

'

'

8.45%

'

'

7.40%

'

'

7.50%

'

'

7.95%

'

'

6.00%

'

'

Debt Instrument Maturity Date

'

'

6-Jun-16

'

'

30-Sep-17

'

'

6-Jun-21

'

'

16-Jul-27

'

'

'

16-Jul-27

'

'

'

'

1-Aug-43

'

'

'

'

19-Dec-13

'

'

6-Oct-23

'

'

19-Sep-24

'

'

3-Oct-25

'

'

9-Oct-26

'

'

14-Sep-29

'

'

19-Dec-33

'

'

Maturities Of Long Term Debt Abstract

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Long Term Debt Maturities Repayments Of Principal In Next Twelve Months

100,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Long Term Debt Maturities Repayments Of Principal In Year Two

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Long Term Debt Maturities Repayments Of Principal In Year Three

40,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Long Term Debt Maturities Repayments Of Principal In Year Four

35,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Long Term Debt Maturities Repayments Of Principal In Year Five

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Long Term Debt Maturities Repayments Of Principal After Year Five

1,100,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Long-term Debt, Total

1,275,000,000

975,000,000

'

40,000,000

40,000,000

'

35,000,000

35,000,000

'

160,000,000

160,000,000

'

'

100,000,000

100,000,000

'

'

200,000,000

200,000,000

'

'

'

'

300,000,000

0

'

100,000,000

100,000,000

'

45,000,000

45,000,000

'

40,000,000

40,000,000

'

55,000,000

55,000,000

'

40,000,000

40,000,000

'

60,000,000

60,000,000

'

100,000,000

100,000,000

Debt Instrument Face Amount

'

'

'

'

'

'

'

'

'

'

'

'

100,000,000

'

'

'

200,000,000

'

'

300,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument Issuance Date

'

'

'

'

'

'

'

'

'

'

'

16-Jul-12

'

'

'

15-Oct-12

'

'

'

'

1-Aug-13

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Proceeds from issuance of debt, net

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

297,200,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument Description

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'issued $300 million of thirty-year, unsecured senior notes with an interest rate of 4.65% and at a discount of .048% or $144,000, which we began to amortize ratably over the expected life of the notes, under the registration statement noted above. We used the net proceeds of $297.2 million from this issuance to finance capital expenditures, to repay $100 million of our 5% medium-term notes due December 19, 2013 at maturity, to repay outstanding short-term, unsecured notes under our commercial paper (CP) program and for general corporate purposes.

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net Earnings Available For Restricted Payments

'Amount available for restricted payments $760,870,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Retained earnings

627,236,000

584,848,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Issuance Discount Percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.05%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument Covenant Description

'The default provisions of some or all of our senior debt include: Failure to make principal or interest payments, Bankruptcy, liquidation or insolvency, Final judgment against us in excess of $1 million that after 60 days is not discharged, satisfied or stayed pending appeal, Specified events under the Employee Retirement Income Security Act of 1974, Change in control, and Failure to observe or perform covenants, including: Interest coverage of at least 1.75 times. Interest coverage was 4.6 times as of October 31, 2013; Funded debt cannot exceed 70% of total capitalization. Funded debt was 59% of total capitalization as of October 31, 2013; Funded debt of all subsidiaries in the aggregate cannot exceed 15% of total capitalization. There is no funded debt of our subsidiaries as of October 31, 2013; Restrictions on permitted liens; Restrictions on paying dividends, on or repurchasing our stock or making investments in subsidiaries; and Restrictions on burdensome agreements.

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Ratio Of Indebtedness To Net Capital

59

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Interest Coverage Ratio

4.6

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Funded Debt Of Subsidiaries

$0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument Redemption [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument Redemption Description

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'redemption price equal to the greater of a) 100% of the principal amount plus any accrued and unpaid interest to the date of redemption, or b) the sum of the present values of the remaining scheduled payments of principal and interest on the notes to be redeemed, discounted to the date of redemption on a semi-annual basis at the Treasury Rate as defined in the indenture, plus 15 basis points and any accrued and unpaid interest to the date of redemption.

'100% of the principal amount plus any accrued and unpaid interest to the date of redemption.

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument Redemption Period Start Date

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1-Aug-13

1-Feb-43

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument Redemption Period End Date

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

31-Jan-43

1-Aug-43

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Short_Term_Debt_Details

Short Term Debt (Details) (USD $)	12 Months Ended
	Oct. 31, 2013	Oct. 31, 2012
Line Of Credit Facility [Line Items]	'	'
Credit Facility Maximum Amount Outstanding During Period	$555,000,000	'
Credit Facility Minimum Amount Outstanding During Period	220,000,000	'
Short-term debt	400,000,000	365,000,000
Maximum [Member]	'	'
Line Of Credit Facility [Line Items]	'	'
Line of Credit Facility Interest Rate During Period	1.12%	'
Minimum [Member]	'	'
Line Of Credit Facility [Line Items]	'	'
Line of Credit Facility Interest Rate During Period	0.23%	'
Weighted Average [Member]	'	'
Line Of Credit Facility [Line Items]	'	'
Line of Credit Facility Interest Rate During Period	0.32%	'
Letter Of Credit [Member]	'	'
Line Of Credit Facility [Line Items]	'	'
Credit Facility Current Borrowing Capacity	10,000,000	10,000,000
Credit Facility Amount Outstanding	2,100,000	3,600,000
Revolving Credit Facility [Member]	'	'
Line Of Credit Facility [Line Items]	'	'
Credit Facility Current Borrowing Capacity	650,000,000	'
Maximum Facility	850,000,000	'
Line Of Credit Commitment Annual Fee	'35,000 plus 8.5 basis points	'
Line Of Credit Facility Frequency Of Commitment Fee Payment	'Annual	'
Maximum Unused Amount On Which Fees Are Payable	650,000,000	'
Credit Facility Interest Rate Description	'30-day LIBOR rate plus from 75 to 125 basis points	'
Credit Facility Covenant Terms	'total debt to total capitalization of no greater than 70%	'
Credit Facility Covenant Compliance	'actual ratio was 59%	'
Credit Facility Maximum Amount Outstanding During Period	10,000,000	'
Credit Facility Minimum Amount Outstanding During Period	0	'
Line of Credit Facility, Expiration Date	1-Oct-17	'
Short-term Debt, Description	'$650 million five-year revolving syndicated credit facility that expires on October 1, 2017. The facility has an option to request an expansion of up to $850 million. On November 1, 2013, we entered into an agreement with the lenders under the facility which increased our borrowing capacity to $850 million. We pay an annual fee of $35,000 plus 8.5 basis points for any unused amount. The facility provides a line of credit for letters of credit of $10 million These letters of credit are used to guarantee claims from self-insurance under our general and automobile liability policies. The credit facility bears interest based on the 30-day London Interbank Offered Rate (LIBOR) plus from 75 to 125 basis points, based on our credit ratings. Amounts borrowed are continuously renewable until the expiration of the facility in 2017 provided that we are in compliance with all terms of the agreement.	'
Revolving Credit Facility [Member] | Maximum [Member]	'	'
Line Of Credit Facility [Line Items]	'	'
Line of Credit Facility Interest Rate During Period	1.12%	'
Revolving Credit Facility [Member] | Minimum [Member]	'	'
Line Of Credit Facility [Line Items]	'	'
Line of Credit Facility Interest Rate During Period	1.12%	'
Revolving Credit Facility [Member] | Weighted Average [Member]	'	'
Line Of Credit Facility [Line Items]	'	'
Line of Credit Facility Interest Rate During Period	1.12%	'
Commercial Paper [Member]	'	'
Line Of Credit Facility [Line Items]	'	'
Credit Facility Current Borrowing Capacity	650,000,000	'
Maximum Facility	850,000,000	'
Credit Facility Interest Rate Description	'interest based on, among other things, the size and maturity date of the note, the frequency of the issuance and our credit ratings, plus a spread of 5 basis points	'
Weighted Average Interest Rate	0.36%	0.42%
Credit Facility Maximum Amount Outstanding During Period	555,000,000	'
Credit Facility Minimum Amount Outstanding During Period	220,000,000	'
Commercial Paper	$400,000,000	$365,000,000
Short-term Debt, Description	'$650 million unsecured CP program that is backstopped by the revolving syndicated credit facility. In conjunction with the exercise of the option in November 2013, the amounts outstanding under the revolving syndicated credit facility and the CP program, either individually or in the aggregate, have been increased to, but cannot exceed, $850 million. The notes issued under the CP program may have maturities not to exceed 397 days from the date of issuance and bear interest based on, among other things, the size and maturity date of the note, the frequency of the issuance and our credit ratings, plus a spread of 5 basis points. Any borrowings under the CP program rank equally with our other unsubordinated and unsecured debt. The notes under the CP program are not registered and are offered and issued pursuant to an exemption from registration.	'
Maximum Number Of Possible Days Outstanding For Commerical Paper Program	'397 days	'
Commercial Paper [Member] | Maximum [Member]	'	'
Line Of Credit Facility [Line Items]	'	'
Line of Credit Facility Interest Rate During Period	0.45%	'
Number Days Outstanding From Issuance Until Maturity	'37 days	'
Commercial Paper [Member] | Minimum [Member]	'	'
Line Of Credit Facility [Line Items]	'	'
Line of Credit Facility Interest Rate During Period	0.23%	'
Number Days Outstanding From Issuance Until Maturity	'1 day	'
Commercial Paper [Member] | Weighted Average [Member]	'	'
Line Of Credit Facility [Line Items]	'	'
Line of Credit Facility Interest Rate During Period	0.32%	'

Stockholders_Equity_Details

Stockholders' Equity (Details) (USD $)

0 Months Ended

3 Months Ended

12 Months Ended

0 Months Ended

0 Months Ended

12 Months Ended

Feb. 04, 2013

Jan. 29, 2013

Feb. 28, 2012

Jan. 05, 2012

Oct. 31, 2013

Jul. 31, 2013

Apr. 30, 2013

Jan. 31, 2013

Oct. 31, 2012

Jul. 31, 2012

Apr. 30, 2012

Jan. 31, 2012

Oct. 31, 2013

Oct. 31, 2012

Oct. 31, 2011

Feb. 04, 2013

Jan. 29, 2013

Feb. 22, 2013

Oct. 31, 2013

Jan. 29, 2013

Oct. 31, 2013

Oct. 31, 2012

Dec. 16, 2005

Sep. 30, 2004

Dec. 16, 2005

Mar. 06, 2009

Dec. 16, 2005

Oct. 31, 2013

Oct. 31, 2013

Oct. 31, 2013

Forward Sale Agreement [Member]

Forward Sale Agreement [Member]

Additional Forward Sale Agreement [Member]

Additional Forward Sale Agreement [Member]

Additional Forward Sale Agreement [Member]

Reclassification Out Of Accumulated Other Comprehensive Income [Member]

Reclassification Out Of Accumulated Other Comprehensive Income [Member]

Common Stock Open Market Purchase Program [Member]

Common Stock Open Market Purchase Program [Member]

ASR Program [Member]

Common Stock Open Market Purchase Program and ASR Program [Member]

Common Stock Open Market Purchase Program and ASR Program [Member]

Employee Stock Purchase Plan [Member]

Dividend Reinvestment Plan [Member]

Share Based Compensation Plans [Member]

Maximum [Member]

Stockholders' Equity [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common Stock, Shares, Outstanding, Beginning Balance

'

'

'

'

'

'

'

72,250,000

'

'

'

72,318,000

72,250,000

72,318,000

72,282,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common Stock, Value, Issued, Beginning Balance

'

'

'

'

'

'

'

$442,461,000

'

'

'

$446,791,000

$442,461,000

$446,791,000

$445,640,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Stock Issued During Period Shares Employee Stock Purchase Plans (ESPP)

'

'

'

'

'

'

'

'

'

'

'

'

33,000

30,000

30,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Stock Issued During Period Value Employee Stock Purchase Plan (ESPP)

'

'

'

'

'

'

'

'

'

'

'

'

1,056,000

894,000

870,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Stock Issued During Period Shares Dividend Reinvestment Plan (DRIP)

'

'

'

'

'

'

'

'

'

'

'

'

720,000

677,000

657,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Stock Issued During Period Value Dividend Reinvestment Plan (DRIP)

'

'

'

'

'

'

'

'

'

'

'

'

22,791,000

20,508,000

18,834,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Shares Issued During Period Shares Incentive Compensation Plan (ICP)

'

'

'

'

'

'

'

'

'

'

'

'

96,000

25,000

149,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Shares Issued During Period Value Incentive Compensation Plan (ICP)

'

'

'

'

'

'

'

'

'

'

'

'

3,065,000

796,000

4,451,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Shares Repurchased During Period Shares Accelerated Share Repurchase (ASR) Plan

'

'

'

-800,000

'

'

'

'

'

'

'

'

'

-800,000

-800,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common Stock Repurchased

'

'

'

'

'

'

'

'

'

'

'

'

'

-26,528,000

-23,004,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Issuance of commons stock shares through public share offering, net of underwriting fees

3,000,000

'

'

'

'

'

'

'

'

'

'

'

3,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Issuance of common stock through public share offering, net of underwriting fees

'

'

'

'

92,640,000

'

'

'

'

'

'

'

92,640,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Expenses From Issuance of Common Stock

'

'

'

'

'

'

'

'

'

'

'

'

-369,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common Stock, Shares, Outstanding, Ending Balance

'

'

'

'

76,099,000

'

'

'

72,250,000

'

'

'

76,099,000

72,250,000

72,318,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common Stock, Value, Issued, Ending Balance

'

'

'

'

561,644,000

'

'

'

442,461,000

'

'

'

561,644,000

442,461,000

446,791,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Accelerated Share Repurchases Initial Price Paid Per Share

'

'

'

$33.77

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Stock Repurchased During Period Value At Initial Price ASR Plan

'

'

'

27,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Accelerated Share Repurchases Settlement Payment Or Receipt

'

'

500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Accelerated Share Repurchases Weighted Average Purchase Price Per Share

'

'

$33.25

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Accelerated Share Repurchases Discount On Weighted Average Purchase Price Per Share

'

'

$0.09

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Accelerated Share Repurchases Final Price Paid Per Share

'

'

$33.16

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Class of Stock [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common Stock Reserved For Future Issuance

'

'

'

'

2,798,000

'

'

'

'

'

'

'

2,798,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

210,000

1,538,000

1,050,000

Authorized Common Stock Repurchases Shares

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

6,000,000

3,000,000

'

'

10,000,000

'

'

'

Additional Authorized Common Stock Repurchases Shares

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

4,000,000

4,000,000

'

'

'

'

Accumulated Other Comprehensive Income Loss [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Accumulated OCIL beginning balance, net of tax

'

'

'

'

'

'

'

-305,000

'

'

'

-452,000

-305,000

-452,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Other comprehensive income (loss) before reclassifications, net of tax

'

'

'

'

'

'

'

'

'

'

'

'

-109,000

-826,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Amounts reclassified, net of tax

'

'

'

'

'

'

'

'

'

'

'

'

130,000

973,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total other comprehensive income

'

'

'

'

'

'

'

'

'

'

'

'

21,000

147,000

78,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Accumulated OCIL ending balance, net of tax

'

'

'

'

-284,000

'

'

'

-305,000

'

'

'

-284,000

-305,000

-452,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Income from Equity Method Investments

'

'

'

'

'

'

'

'

'

'

'

'

26,056,000

23,904,000

24,027,000

'

'

'

'

'

-215,000

-1,594,000

'

'

'

'

'

'

'

'

Other income (expense) income taxes

'

'

'

'

'

'

'

'

'

'

'

'

-8,612,000

-9,116,000

-8,218,000

'

'

'

'

'

85,000

621,000

'

'

'

'

'

'

'

'

Net Income

'

'

'

'

-5,003,000

-2,293,000

55,790,000

85,923,000

-1,959,000

-4,613,000

50,192,000

76,227,000

134,417,000

119,847,000

113,568,000

'

'

'

'

'

-130,000

-973,000

'

'

'

'

'

'

'

'

Common Stock Underwriting Agreement [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Maximum Number Of Shares To Be Purchased

'

4,600,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Forward Contract Shares

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,000,000

'

'

600,000

'

'

'

'

'

'

'

'

'

'

Equity Issuance, Date Direct Shares

'

'

'

'

'

'

'

'

'

'

'

'

4-Feb-13

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common Stock Issued, Value

$92,600,000

'

'

'

'

'

'

'

'

'

'

'

$119,552,000

$22,198,000

$24,155,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common Stock Issued, Shares

3,000,000

'

'

'

'

'

'

'

'

'

'

'

3,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Price Per Share Gross

$32

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Underwriter Discount

$1.12

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net Settlement Price Per Share

$30.88

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$30.88

'

'

'

'

'

'

'

'

'

'

'

'

Forward Shares To Be Borrowed By Forward Counterparty

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,000,000

'

600,000

'

'

'

'

'

'

'

'

'

'

'

'

Option to Purchase Settlement Date

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

22-Feb-13

'

'

'

'

'

'

'

'

'

'

'

Shares Subject To Underwriters Option To Purchase

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

600,000

'

'

'

'

'

'

'

'

'

'

'

'

Financial_Instruments_Related_1

Financial Instruments & Related Fair Value (Details) (USD $)	12 Months Ended
	Oct. 31, 2013	Oct. 31, 2012
	MMBTU	MMBTU
Financial Instruments And Related Fair Value Detail [Abstract]	'	'
Fair Value Measurement Transfers Between Levels Activity	'We have had no transfers between any level during the years ended October 31, 2013 and 2012.	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Derivatives Held For Distribution Operations	$1,834,000	$3,153,000
Total trading securities	3,194,000	2,288,000
Total Recurring Fair Value Assets	5,028,000	5,441,000
Long Term Debt Fair Value	1,409,892,000	1,163,227,000
Total Long-term Debt	1,275,000,000	975,000,000
Gas Options Total Coverage	25,400,000	35,800,000
Amount Of Loss Recognized On Derivatives	6,303,000	8,000
Amount Of Loss Deferred Under PGA Procedures	6,303,000	8,000
Percentage Of Annual Gas Purchase Options and All Other Costs Related To Hedging Approved For Recovery Under TIP	1.00%	'
Derivative [Line Items]	'	'
Gas Purchase Options Current Assets	1,834,000	3,153,000
Concentration Risk [Line Items]	'	'
Concentration Risk, Benchmark Description	'“Trade accounts receivable” in “Current Assets” in the Consolidated Balance Sheets	'
Concentration Risk, Customer	'We are exposed to credit risk as a result of transactions for the purchase and sale of products and services and management agreements of our transportation capacity, storage capacity and supply contracts with major companies in the energy industry and within our utility operations serving industrial, commercial, power generation, residential and municipal energy consumers. These transactions principally occur in the eastern, gulf coast and mid-west regions of the United States. We believe that this geographic concentration does not contribute significantly to our overall exposure to credit risk. Credit risk associated with trade accounts receivable for the natural gas distribution segment is mitigated by the large number of individual customers and diversity in our customer base. We enter into contracts with third parties to buy and sell natural gas. A significant portion of these transactions are with, or are associated with, energy producers, utility companies, off-system municipalities and natural gas marketers.	'
Accounts Receivable [Member] | Credit Concentration Risk [Member]	'	'
Concentration Risk [Line Items]	'	'
Concentration Risk, Percentage	17.00%	'
Concentration Risk Amount	13,400,000	'
Money Market Funds Member	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Total trading securities	380,000	243,000
Equity Funds Member	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Total trading securities	2,814,000	2,045,000
Quoted Prices In Active Markets [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Derivatives Held For Distribution Operations	1,834,000	3,153,000
Total Recurring Fair Value Assets	5,028,000	5,441,000
Quoted Prices In Active Markets [Member] | Money Market Funds Member	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Total trading securities	380,000	243,000
Quoted Prices In Active Markets [Member] | Equity Funds Member	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Total trading securities	2,814,000	2,045,000
Significant Other Observable Inputs [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Derivatives Held For Distribution Operations	0	0
Total Recurring Fair Value Assets	0	0
Significant Other Observable Inputs [Member] | Money Market Funds Member	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Total trading securities	0	0
Significant Other Observable Inputs [Member] | Equity Funds Member	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Total trading securities	0	0
Significant Unobservable Inputs [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Derivatives Held For Distribution Operations	0	0
Total Recurring Fair Value Assets	0	0
Significant Unobservable Inputs [Member] | Money Market Funds Member	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Total trading securities	0	0
Significant Unobservable Inputs [Member] | Equity Funds Member	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Total trading securities	$0	$0

Commitment_Contingencies_Detai

Commitment & Contingencies (Details) (USD $)

12 Months Ended

96 Months Ended

96 Months Ended

0 Months Ended

60 Months Ended

12 Months Ended

12 Months Ended

Oct. 31, 2013

Oct. 31, 2012

Oct. 31, 2011

Oct. 31, 1997

Oct. 31, 2013

Oct. 31, 2012

Oct. 31, 2013

Oct. 31, 2012

Feb. 29, 2020

Oct. 31, 2010

Feb. 29, 2020

Mar. 31, 2012

Aug. 31, 2013

Dec. 31, 2018

Dec. 31, 2013

Oct. 31, 2014

Oct. 31, 2014

Dec. 31, 2013

Oct. 31, 2013

Oct. 31, 2013

Oct. 31, 2013

Oct. 31, 2013

Oct. 31, 2013

Oct. 31, 2013

Oct. 31, 2013

Apr. 11, 2012

Oct. 31, 2013

Oct. 31, 2013

Oct. 31, 2013

Oct. 31, 2013

Oct. 31, 2013

Letter Of Credit [Member]

Letter Of Credit [Member]

Environmental Restoration Costs [Member]

Environmental Restoration Costs [Member]

Tennessee Regulatory Authority [Member]

Tennessee Regulatory Authority [Member]

Tennessee Regulatory Authority [Member]

Tennessee Regulatory Authority [Member]

NCUC [Member]

NCUC [Member]

NCUC [Member]

PSCSC [Member]

PSCSC [Member]

PSCSC [Member]

Hickory North Carolina Site [Member]

Reidsville North Carolina Site [Member]

Nashville MGP [Member]

Huntersville LNG Facility [Member]

Nashville LNG Facility [Member]

Manufactured Gas Plant Sites [Member]

Huntersville LNG Groundwanter Remediation [Member]

Huntersville LNG Groundwanter Remediation [Member]

LNG Facility And Underground Storage Tank Liability [Member]

Pipeline And Storage Capacity Contacts [Member]

Gas Supply Contracts [Member]

Telecommunications And Technology Outsourcing Contracts [Member]

Others [Member]

General Rate Application Settlement 2012 [Member]

General Rate Application Settlement 2012 [Member]

Environmental Restoration Costs [Member]

Environmental Restoration Costs [Member]

Environmental Restoration Costs [Member]

Environmental Restoration Costs [Member]

Environmental Restoration Costs [Member]

Settlement With Office Of Regulatory Staff October 2013 [Member]

Environmental Restoration Costs [Member]

Environmental Restoration Costs [Member]

General Rate Application Settlement 2012 [Member]

General Rate Application Settlement 2012 [Member]

General Rate Application Settlement 2013 [Member]

General Rate Application Settlement 2013 [Member]

General Rate Application Settlement 2013 [Member]

Settlement With Office Of Regulatory Staff October 2013 [Member]

Settlement With Office Of Regulatory Staff October 2013 [Member]

Commitments and Contingencies Disclosure [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Operating Lease Payments

$4,729,000

$3,712,000

$4,496,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Operating Leases Future Minimum Payments Due Current

4,543,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Operating Leases Future Minimum Payments Due In Two Years

4,592,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Operating Leases Future Minimum Payments Due In Three Years

4,491,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Operating Leases Future Minimum Payments Due In Four Years

4,297,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Operating Leases Future Minimum Payments Due In Five Years

4,225,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Operating Leases Future Minimum Payments Due Thereafter

31,496,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Operating Leases Future Minimum Payments Due

53,644,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Unrecorded Unconditional Purchase Obligation [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Unrecorded Unconditional Purchase Obligation Balance On First Anniversary

212,782,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

170,430,000

6,356,000

11,045,000

24,951,000

Unrecorded Unconditional Purchase Obligation Balance On Second Anniversary

162,083,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

157,407,000

0

4,676,000

0

Unrecorded Unconditional Purchase Obligation Balance On Third Anniversary

151,304,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

150,544,000

0

760,000

0

Unrecorded Unconditional Purchase Obligation Balance On Fourth Anniversary

145,494,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

145,494,000

0

0

0

Unrecorded Unconditional Purchase Obligation Balance On Fifth Anniversary

142,983,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

142,983,000

0

0

0

Unrecorded Unconditional Purchase Obligation Due After Fifth Year

781,549,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

781,549,000

0

0

0

Unrecorded Unconditional Purchase Obligation

1,596,195,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,548,407,000

6,356,000

16,481,000

24,951,000

MGP Sites Under Settlement

'

'

'

9

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

MGP Sites Not Under Settlement

4

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Site Contingency [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Site Contingency Environmental Remediation Costs Recognized

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,500,000

600,000

1,500,000

4,600,000

500,000

'

'

'

'

'

'

'

'

Accrual For Environmental Loss Contingencies Gross

1,300,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,100,000

100,000

'

100,000

'

'

'

'

Administrative Consent Order Fine

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

40,000

'

'

'

'

'

Administrative Consent Order Unpaid Annual Fees

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

18,000

'

'

'

'

'

Administrative Consent Order Investigative And Administrative Cost

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,860

'

'

'

'

'

Number Of Underground Storage Tanks In Operation

2

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Site Contingency, Unasserted Claims

'0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Regulatory Assets [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Regulatory Assets

246,306,000

293,104,000

'

'

'

'

9,416,000

10,202,000

'

1,000,000

'

2,000,000

'

'

6,300,000

'

200,000

200,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Amortization Time Period For Specified Expenses

'

'

'

'

'

'

'

'

'8 years

'

'8 years

'

'5 years

'5 years

'

'1 year

'1 year

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Line Of Credit Facility [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Credit Facility Amount Outstanding

'

'

'

'

$2,100,000

$3,600,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Public Utilities Description Of Regulatory Scope

'Our utility operations are regulated by the NCUC, PSCSC and TRA as to rates, service area, adequacy of service, safety standards, extensions and abandonment of facilities, accounting and depreciation. We are also regulated by the NCUC as to the issuance of long-term debt and equity securities. The NCUC and the PSCSC regulate our gas purchasing practices under a standard of prudence and audit our gas cost accounting practices. The TRA regulates our gas purchasing practices under a gas supply incentive program which compares our actual costs to market pricing benchmarks. As part of this jurisdictional oversight, all three regulatory commissions address our gas supply hedging activities. Additionally, all three regulatory commissions allow for recovery of uncollectible gas costs through the PGA. The portion of uncollectibles related to gas costs is recovered through the deferred account and only the non-gas costs, or margin, portion of uncollectibles is included in base rates and uncollectibles expense. Our three regulatory commissions have authorized us to utilize deferral accounting in connection with environmental costs.

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Commitment_Contingencies_Long_

Commitment & Contingencies - Long Term Contracts (Details) (Maximum [Member])	12 Months Ended
	Oct. 31, 2013
Pipeline And Storage Capacity Contacts [Member]	'
Long Term Purchase Commitment [Line Items]	'
Long Term Purchase Commitment Time Period	'22 years
Gas Supply Contracts [Member]	'
Long Term Purchase Commitment [Line Items]	'
Long Term Purchase Commitment Time Period	'1 years
Telecommunications And Technology Outsourcing Contracts [Member]	'
Long Term Purchase Commitment [Line Items]	'
Long Term Purchase Commitment Time Period	'3 years

Employee_Benefit_Plans_Details

Employee Benefit Plans (Details) (USD $)	0 Months Ended	12 Months Ended
	Dec. 31, 2007	Oct. 31, 2013	Oct. 31, 2012	Oct. 31, 2011
Defined Benefit Plan Disclosure [Line Items]	'	'	'	'
Term Life Insurance Premiums Paid By Employer For Vp And Above	'	$27,000	$43,000	$56,000
Officers And Director Level Employees	'	28,000	25,000	24,000
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Noncurrent assets	'	28,258,000	0	'
Amounts Not Yet Recognized as a Component of Cost and Recognized in a Deferred Regulatory Account	'	'	'	'
Regulatory asset	'	-246,306,000	-293,104,000	'
Defined Contribution Plans Disclosure [Abstract]	'	'	'	'
Current Liability	'	199,000	160,000	'
Noncurrent Liability	'	3,328,000	2,412,000	'
Plan 401 K [Member]	'	'	'	'
Defined Contribution Plans Disclosure [Abstract]	'	'	'	'
Employer Contribution to Plan	'	5,688,000	5,400,000	5,203,000
Defined Contribution Plan, Maximum Annual Contribution Per Employee, Percent	'	5.00%	'	'
Description Of Defined Contribution Pension And Other Postretirement Plans	'	'We maintain a 401(k) plan that is a profit-sharing plan under Section 401(a) of the Internal Revenue Code of 1986, as amended (the Tax Code), which includes qualified cash or deferred arrangements under Tax Code Section 401(k). The 401(k) plan is subject to the provisions of the Employee Retirement Income Security Act. Eligible employees who have completed 30 days of continuous service and have attained age 18 are eligible to participate. Participants may defer a portion of their base salary and cash incentive payments to the plan, and we match a portion of their contributions. Employee contributions vest immediately, and company contributions vest after six months of service. Employees receive a company match of 100% up to the first 5% of eligible pay contributed. Employees may contribute up to 50% of eligible pay to the 401(k) on a pre-tax basis, up to the Tax Code annual contribution and compensation limits. We automatically enroll all eligible non-participating employees in the 401(k) plan at a 2% contribution rate unless the employee chooses not to participate by notifying our record keeper. For employees who are automatically enrolled in the 401(k) plan, we automatically increase their contributions by 1% each year to a maximum of 5% unless the employee chooses to opt out of the automatic increase by contacting our record keeper. If the employee does not make an investment election, employee contributions and matches are automatically invested in a diversified portfolio of stocks and bonds. Participants may direct up to 20% of their contributions and company matching contributions as an investment in the Piedmont Stock Fund. Employees may change their contribution rate and investments at any time.	'	'
Standard Eligibility Age For Defined Contribution Plan	'	'18 years	'	'
Service Required For Eligibility In Defined Contribution Plan	'	'30 days	'	'
Employer Match Percentage	'	100.00%	'	'
Employee Contribution Cap	'	50.00%	'	'
Employee Contribution Rate At Enrollment	'	2.00%	'	'
Contribution Annual Automatic Deferral Increase	'	1.00%	'	'
Employee Contribution Automatic Increase Rate Cap	'	5.00%	'	'
Investment In Company Stock Cap	'	20.00%	'	'
Money Purchase Pension Plan [Member]	'	'	'	'
Defined Contribution Plans Disclosure [Abstract]	'	'	'	'
Employer Contribution to Plan	'	700,000	'	'
Employer Contribution Percentage	'	4.00%	'	'
Description Of Defined Contribution Pension And Other Postretirement Plans	'	'Employees hired or rehired after December 31, 2007 cannot participate in the qualified pension plan but are participants in the Money Purchase Pension (MPP) plan, a defined contribution pension plan that allows the employee to direct the investments and assume the risk of investment returns. A defined contribution plan specifies the amount of the employer’s annual contribution to individual participant accounts established for the retirement benefit. Eligible employees who have completed 30 days of continuous service and have attained age 18 are eligible to participate. Under the MPP plan, we annually deposit a percentage of each participant’s pay into an account of the MPP plan. This contribution equals 4% of the participant’s compensation plus an additional 4% of compensation above the social security wage base up to the Internal Revenue Service (IRS) compensation limit. The participant is vested in this plan after three years of service.	'	'
Standard Eligibility Age For Defined Contribution Plan	'	'18 years	'	'
Service Required For Eligibility In Defined Contribution Plan	'	'30 days	'	'
Employer Contribution Percentage Above IRS Limit	'	4.00%	'	'
Plan Vesting Period Defined Contribution Plan	'	'3 years	'	'
Defined Contribution Plans Estimated Future Employer Contributions In Next Fiscal Year	'	885,000	'	'
Defined Contribution Restoration Plan [Member]	'	'	'	'
Defined Contribution Plans Disclosure [Abstract]	'	'	'	'
Employer Contribution to Plan	'	434,000	422,000	'
Description Of Defined Contribution Pension And Other Postretirement Plans	'	'We have a non-qualified defined contribution restoration plan (DCR plan) for all officers at the vice president level and above where benefits payable under the plan are informally funded annually through a rabbi trust with a bank as the trustee. We contribute 13% of the total cash compensation (base salary, short-term incentive and MVP incentive) that exceeds the IRS compensation limit to the DCR plan account of each covered executive. Participants may not contribute to the DCR plan. Vesting under the DCR plan is five-year cliff vesting, including service prior to adoption of the plan on January 1, 2009, of annual company contributions, and prospective five-year cliff vesting for the one-time opening balances of four Vice Presidents to compensate them for the loss of future benefits under this DCR plan as compared with a terminated SERP. Participants in the DCR plan may provide instructions to us for the deemed investment of their plan accounts. Distribution will occur upon separation of service or death of the participant.	'	'
Employer Contribution Percentage Above IRS Limit	'	13.00%	'	'
Plan Vesting Period Defined Contribution Plan	'	'5 years	'	'
Vice Presidents Eligible For One Time Contribution New DCR Plan	'	4	'	'
Voluntary Deferral Plan [Member]	'	'	'	'
Defined Contribution Plans Disclosure [Abstract]	'	'	'	'
Employer Contribution to Plan	'	0	'	'
Deferral Limit As Percentage Of Base Salary	'	50.00%	'	'
Plan Deferral Limit As Percentage Of Annual Incentive Pay	'	95.00%	'	'
Distribution Deferral Time Period Minimum In Years	'	'2 years	'	'
Private Equity Funds [Member]	'	'	'	'
Amounts Not Yet Recognized as a Component of Cost and Recognized in a Deferred Regulatory Account	'	'	'	'
Initial Unfunded Subscription Balance	'	12,000,000	'	'
Net Asset Value Unfunded Committments	'	7,400,000	'	'
Qualified Pension [Member]	'	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'	'
Defined Benefit Plans General Information	'	'We have a noncontributory, tax-qualified defined benefit pension plan (qualified pension plan) for our eligible employees. A defined benefit plan specifies the amount of benefit that an eligible participant eventually will receive upon retirement using information about that participant. An employee became eligible on the January 1 or July 1 following either the date on which he or she attained age 30 or attained age 21 and completed 1,000 hours of service during the 12-month period commencing on the employment date. Plan benefits are generally based on credited years of service and the level of compensation during the five consecutive years of the last ten years prior to retirement or termination during which the participant received the highest compensation. Our policy is to fund the plan in an amount not in excess of the amount that is deductible for income tax purposes. The qualified pension plan is closed to employees hired after December 31, 2007. Employees hired prior to January 1, 2008 continue to participate in the qualified pension plan. Employees are vested after five years of service and can be credited with up to a total of 35 years of service. When a vested employee leaves the company, his benefit payment will be calculated as the greater of the accrued benefit as of December 31, 2007 under a specific formula plus the accrued benefit calculated under a second formula for years of service after December 31, 2007, or the benefit for all years of service up to 35 years under the second formula.	'	'
Estimated Future Employee Contributions Next Fiscal Year	'	20,000,000	'	'
Reconciliation Of Changes In Plan Benefit Obligations And Fair Value Of Assets [Abstract]	'	'	'	'
Accumulated Benefit Obligation At Year End	'	230,175,000	245,361,000	'
Change In Benefit Obligation	'	'	'	'
Obligation at beginning of year	'	293,327,000	236,632,000	'
Service cost	'	12,005,000	9,573,000	8,508,000
Interest cost	'	9,946,000	10,640,000	11,024,000
Actuarial (gain) loss	'	-24,859,000	54,852,000	'
Participant contributions	'	0	0	'
Administrative expenses	'	-534,000	-420,000	'
Benefit payments	'	-17,482,000	-17,950,000	'
Obligation at end of year	'	272,403,000	293,327,000	236,632,000
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at beginning of year	'	272,337,000	259,511,000	'
Actual return on plan assets	'	26,340,000	31,196,000	'
Employer contributions	'	20,000,000	0	'
Participant contributions	'	0	0	'
Administrative expenses	'	-534,000	-420,000	'
Benefit payments	'	-17,482,000	-17,950,000	'
Fair value at end of year	'	300,661,000	272,337,000	259,511,000
Funded status at year end - (under) over	'	28,258,000	-20,990,000	'
Noncurrent assets	'	28,258,000	0	'
Current liabilities	'	0	0	'
Noncurrent liabilities	'	0	-20,990,000	'
Net amount recognized	'	28,258,000	-20,990,000	'
Amounts Not Yet Recognized as a Component of Cost and Recognized in a Deferred Regulatory Account	'	'	'	'
Unrecognized transition obligation	'	0	0	'
Unrecognized prior service (cost) credit	'	17,243,000	19,441,000	'
Unrecognized actuarial loss	'	-96,338,000	-137,633,000	'
Cumulative Employer Contribution In Excess Of Cost	'	107,353,000	97,202,000	'
Horizon For DBPP Long Term Rates Of Return	'	'20 years	'	'
Benefit Obligation Weighted Average Assumptions [Abstract]	'	'	'	'
Discount Rate	'	4.55%	3.51%	'
Rate Of Compensation Increase	'	3.72%	3.76%	'
Net Periodic Benefits Cost Weighted Average Assumptions [Abstract]	'	'	'	'
Discount Rate	'	3.51%	4.67%	5.47%
Expected Long Term Rate Of Return On Plan Assets	'	8.00%	8.00%	8.00%
Rate Of Compensation Increase	'	3.76%	3.78%	3.87%
Defined Benefit Plan Estimated Future Benefit Payments Abstract	'	'	'	'
2014	'	25,918,000	'	'
2015	'	16,918,000	'	'
2016	'	15,169,000	'	'
2017	'	16,154,000	'	'
2018	'	18,672,000	'	'
2019 - 2023	'	106,226,000	'	'
Defined Benefit Plan Net Periodic Benefit Cost Abstract	'	'	'	'
Service cost	'	12,005,000	9,573,000	8,508,000
Interest cost	'	9,946,000	10,640,000	11,024,000
Expected return on plan assets	'	-21,105,000	-20,289,000	-20,608,000
Amortization of transition obligation	'	0	0	0
Amortization of prior service cost (credit)	'	-2,198,000	-2,198,000	-2,198,000
Amortization of net loss	'	11,202,000	5,966,000	3,547,000
Net periodic benefit (income) cost	'	9,850,000	3,692,000	273,000
Other Changes In Plan Assets And Benefit Obligatin Recognized Through Regulatory Asset Or Liability [Abstract]	'	'	'	'
Prior service cost	'	0	0	0
Net loss (gain)	'	-30,094,000	43,945,000	17,539,000
Amounts Recognized As Component Of Net Periodic Benefit Cost [Abstract]	'	'	'	'
Amortization of transition obligation	'	0	0	0
Amortization of net loss	'	11,202,000	5,966,000	3,547,000
Amortization of prior service cost (credit)	'	-2,198,000	-2,198,000	-2,198,000
Total recognized in regulatory asset (liability)	'	-39,098,000	40,177,000	16,190,000
Total Recognized In Net Periodic Benefit Cost And Regulatory Asset (Liability)	'	-29,248,000	43,869,000	16,463,000
Estimated Amortization And Expected Refunds [Abstract]	'	'	'	'
Amortization of unrecognized prior service cost (credit)	'	-2,198,000	'	'
Amortization of unrecognized actuarial loss	'	7,138,000	'	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Weighted Average Asset Allocations	'	100.00%	100.00%	'
Defined Benefit Plan Fair Value Of Plan Assets	'	300,661,000	272,337,000	259,511,000
Reconciliation Of Plan Assets Classified As Level 3 Roll Forward	'	'	'	'
Fair value at beginning of year	'	272,337,000	259,511,000	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	300,661,000	272,337,000	259,511,000
Standard Eligibility Age For Defined Benefit Plan	'	'30 years	'	'
Duration To Complete Service Requirement	'	'12 months	'	'
Maximum Credited Service Period	'	'35 years	'	'
Period Of Compensation For Benefit Calculation	'	'10 years	'	'
Years Of Highest Compensation For Benefit Calculation	'	'5 years	'	'
Plan Vesting Period Defined Benefit Plan	'	'5 years	'	'
Qualified Pension [Member] | Amounts Not Yet Recognized As Component Of Pension Liability [Member]	'	'	'	'
Amounts Not Yet Recognized as a Component of Cost and Recognized in a Deferred Regulatory Account	'	'	'	'
Regulatory asset	'	-79,095,000	-118,192,000	'
Qualified Pension [Member] | Minimum [Member]	'	'	'	'
Actual return on plan assets:	'	'	'	'
Standard Eligibility Age For Defined Benefit Plan	'	'21 years	'	'
Qualified Pension [Member] | Cash [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	5,722,000	5,346,000	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Weighted Average Asset Allocations	'	2.00%	2.00%	'
Defined Benefit Plan Fair Value Of Plan Assets	'	5,722,000	5,346,000	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	5,722,000	5,346,000	'
Qualified Pension [Member] | Total Fixed Income Securities [Member]	'	'	'	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Weighted Average Asset Allocations	'	38.00%	45.00%	'
Target Plan Asset Allocations	'	45.00%	'	'
Qualified Pension [Member] | US Treasuries [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	24,078,000	17,544,000	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Weighted Average Asset Allocations	'	8.00%	6.00%	'
Defined Benefit Plan Fair Value Of Plan Assets	'	24,078,000	17,544,000	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	24,078,000	17,544,000	'
Qualified Pension [Member] | Long Duration Bonds [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	34,041,000	63,565,000	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Weighted Average Asset Allocations	'	11.00%	23.00%	'
Defined Benefit Plan Fair Value Of Plan Assets	'	34,041,000	63,565,000	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	34,041,000	63,565,000	'
Qualified Pension [Member] | Corporate Bonds [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	42,701,000	26,368,000	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Weighted Average Asset Allocations	'	14.00%	10.00%	'
Defined Benefit Plan Fair Value Of Plan Assets	'	42,701,000	26,368,000	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	42,701,000	26,368,000	'
Qualified Pension [Member] | High Yield Bonds [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	14,680,000	13,777,000	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Weighted Average Asset Allocations	'	5.00%	5.00%	'
Defined Benefit Plan Fair Value Of Plan Assets	'	14,680,000	13,777,000	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	14,680,000	13,777,000	'
Qualified Pension [Member] | Collateralized Mortgage Backed Securities [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	1,098,000	1,513,000	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Weighted Average Asset Allocations	'	0.00%	1.00%	'
Defined Benefit Plan Fair Value Of Plan Assets	'	1,098,000	1,513,000	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	1,098,000	1,513,000	'
Qualified Pension [Member] | Municipals [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	0	345,000	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Weighted Average Asset Allocations	'	0.00%	0.00%	'
Defined Benefit Plan Fair Value Of Plan Assets	'	0	345,000	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	0	345,000	'
Qualified Pension [Member] | Derivatives [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	-11,000	-89,000	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Weighted Average Asset Allocations	'	0.00%	0.00%	'
Defined Benefit Plan Fair Value Of Plan Assets	'	-11,000	-89,000	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	-11,000	-89,000	'
Qualified Pension [Member] | Derivatives [Member] | Maximum [Member]	'	'	'	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Investment Limititation Percentage	'	10.00%	'	'
Qualified Pension [Member] | Total Equity Securities	'	'	'	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Weighted Average Asset Allocations	'	43.00%	36.00%	'
Target Plan Asset Allocations	'	35.00%	'	'
Qualified Pension [Member] | Large Cap Core Index [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	12,023,000	10,260,000	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Weighted Average Asset Allocations	'	4.00%	4.00%	'
Defined Benefit Plan Fair Value Of Plan Assets	'	12,023,000	10,260,000	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	12,023,000	10,260,000	'
Qualified Pension [Member] | Large Cap Value [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	16,908,000	10,427,000	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Weighted Average Asset Allocations	'	6.00%	4.00%	'
Defined Benefit Plan Fair Value Of Plan Assets	'	16,908,000	10,427,000	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	16,908,000	10,427,000	'
Qualified Pension [Member] | Large Cap Growth [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	17,823,000	15,252,000	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Weighted Average Asset Allocations	'	6.00%	6.00%	'
Defined Benefit Plan Fair Value Of Plan Assets	'	17,823,000	15,252,000	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	17,823,000	15,252,000	'
Qualified Pension [Member] | Small Cap Value [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	30,831,000	26,335,000	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Weighted Average Asset Allocations	'	10.00%	10.00%	'
Defined Benefit Plan Fair Value Of Plan Assets	'	30,831,000	26,335,000	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	30,831,000	26,335,000	'
Qualified Pension [Member] | Common Trust Fund International Value [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	24,460,000	'	'
Amounts Not Yet Recognized as a Component of Cost and Recognized in a Deferred Regulatory Account	'	'	'	'
Net Asset Value Redemption Notice Period	'	'5 days	'	'
Net Asset Value Redemption Frequency	'	'Daily	'	'
Net Asset Value Redemption Restriction Description	'	'None	'	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Weighted Average Asset Allocations	'	8.00%	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	24,460,000	'	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	24,460,000	'	'
Qualified Pension [Member] | International Value [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	'	14,376,000	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Weighted Average Asset Allocations	'	'	5.00%	'
Defined Benefit Plan Fair Value Of Plan Assets	'	'	14,376,000	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	'	14,376,000	'
Qualified Pension [Member] | Common Trust Fund International Growth [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at beginning of year	'	18,678,000	'	'
Fair value at end of year	'	27,270,000	'	'
Amounts Not Yet Recognized as a Component of Cost and Recognized in a Deferred Regulatory Account	'	'	'	'
Net Asset Value Redemption Notice Period	'	'30 days	'	'
Net Asset Value Redemption Frequency	'	'Monthly	'	'
Net Asset Value Redemption Restriction Description	'	'None	'	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Weighted Average Asset Allocations	'	9.00%	7.00%	'
Defined Benefit Plan Fair Value Of Plan Assets	'	27,270,000	'	'
Reconciliation Of Plan Assets Classified As Level 3 Roll Forward	'	'	'	'
Fair value at beginning of year	'	18,678,000	'	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	27,270,000	'	'
Qualified Pension [Member] | Total Real Estate [Member]	'	'	'	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Weighted Average Asset Allocations	'	5.00%	6.00%	'
Target Plan Asset Allocations	'	5.00%	'	'
Qualified Pension [Member] | Global Reit [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	15,042,000	16,252,000	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Weighted Average Asset Allocations	'	5.00%	6.00%	'
Defined Benefit Plan Fair Value Of Plan Assets	'	15,042,000	16,252,000	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	15,042,000	16,252,000	'
Qualified Pension [Member] | Total Other Investments [Member]	'	'	'	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Weighted Average Asset Allocations	'	12.00%	11.00%	'
Target Plan Asset Allocations	'	15.00%	'	'
Qualified Pension [Member] | Hedge Funds [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at beginning of year	'	16,995,000	'	'
Fair value at end of year	'	18,571,000	'	'
Amounts Not Yet Recognized as a Component of Cost and Recognized in a Deferred Regulatory Account	'	'	'	'
Net Asset Value Redemption Notice Period	'	'65 days	'	'
Net Asset Value Redemption Frequency	'	'Quarterly	'	'
Net Asset Value Redemption Restriction Description	'	'Redeemed in whole or part but not less than the minimum redemption amount for each currency. Redemption within one year of purchase is subject to 1.5% redemption fee. Redeemed on "first in first out" basis. None of our investment is subject to the redemption fee. Fund's Board of Directors may limit or suspend share redemptions until a further notification ending suspension. No such notification has been received as of October 31, 2013.	'	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Weighted Average Asset Allocations	'	6.00%	6.00%	'
Defined Benefit Plan Fair Value Of Plan Assets	'	18,571,000	'	'
Reconciliation Of Plan Assets Classified As Level 3 Roll Forward	'	'	'	'
Fair value at beginning of year	'	16,995,000	'	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	18,571,000	'	'
Qualified Pension [Member] | Private Equity Funds [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at beginning of year	'	3,522,000	'	'
Fair value at end of year	'	4,659,000	'	'
Amounts Not Yet Recognized as a Component of Cost and Recognized in a Deferred Regulatory Account	'	'	'	'
Net Asset Value Redemption Frequency	'	'Limited	'	'
Net Asset Value Redemption Restriction Description	'	'Investors have only very limited withdrawal rights for specific legal or regulatory reasons. Any transfer of interest will be subject to approval.	'	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Weighted Average Asset Allocations	'	2.00%	1.00%	'
Target Plan Asset Allocations	'	5.00%	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	4,659,000	'	'
Reconciliation Of Plan Assets Classified As Level 3 Roll Forward	'	'	'	'
Fair value at beginning of year	'	3,522,000	'	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	4,659,000	'	'
Qualified Pension [Member] | Private Equity Funds [Member] | Maximum [Member]	'	'	'	'
Amounts Not Yet Recognized as a Component of Cost and Recognized in a Deferred Regulatory Account	'	'	'	'
Net Asset Value Liquidating Investment Remaining Period	'	'12 years	'	'
Qualified Pension [Member] | Private Equity Funds [Member] | Minimum [Member]	'	'	'	'
Amounts Not Yet Recognized as a Component of Cost and Recognized in a Deferred Regulatory Account	'	'	'	'
Net Asset Value Liquidating Investment Remaining Period	'	'10 years	'	'
Qualified Pension [Member] | Commodities [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at beginning of year	'	11,871,000	'	'
Fair value at end of year	'	10,765,000	'	'
Amounts Not Yet Recognized as a Component of Cost and Recognized in a Deferred Regulatory Account	'	'	'	'
Net Asset Value Redemption Notice Period	'	'35 days	'	'
Net Asset Value Redemption Frequency	'	'Monthly	'	'
Net Asset Value Redemption Restriction Description	'	'Redemption within one year of purchase is subject to 1% redemption fee. None of our investment is subject to the redemption fee. If 95% or more of the balance is requested, 95% of the balance will be paid within 30 days. Any outstanding balance or interest owed will be paid after the annual audit is complete.	'	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Weighted Average Asset Allocations	'	4.00%	4.00%	'
Defined Benefit Plan Fair Value Of Plan Assets	'	10,765,000	'	'
Reconciliation Of Plan Assets Classified As Level 3 Roll Forward	'	'	'	'
Fair value at beginning of year	'	11,871,000	'	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	10,765,000	'	'
Qualified Pension [Member] | Total Investments [Member]	'	'	'	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Weighted Average Asset Allocations	'	100.00%	100.00%	'
Qualified Pension [Member] | Quoted Prices In Active Markets [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	112,879,000	112,022,000	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Weighted Average Asset Allocations	'	37.00%	41.00%	'
Defined Benefit Plan Fair Value Of Plan Assets	'	112,879,000	112,022,000	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	112,879,000	112,022,000	'
Qualified Pension [Member] | Quoted Prices In Active Markets [Member] | Cash [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	5,566,000	5,346,000	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	5,566,000	5,346,000	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	5,566,000	5,346,000	'
Qualified Pension [Member] | Quoted Prices In Active Markets [Member] | US Treasuries [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	0	0	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	0	0	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	0	0	'
Qualified Pension [Member] | Quoted Prices In Active Markets [Member] | Long Duration Bonds [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	0	0	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	0	0	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	0	0	'
Qualified Pension [Member] | Quoted Prices In Active Markets [Member] | Corporate Bonds [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	0	0	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	0	0	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	0	0	'
Qualified Pension [Member] | Quoted Prices In Active Markets [Member] | High Yield Bonds [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	14,680,000	13,777,000	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	14,680,000	13,777,000	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	14,680,000	13,777,000	'
Qualified Pension [Member] | Quoted Prices In Active Markets [Member] | Collateralized Mortgage Backed Securities [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	0	0	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	0	0	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	0	0	'
Qualified Pension [Member] | Quoted Prices In Active Markets [Member] | Municipals [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	0	0	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	0	0	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	0	0	'
Qualified Pension [Member] | Quoted Prices In Active Markets [Member] | Derivatives [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	6,000	-3,000	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	6,000	-3,000	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	6,000	-3,000	'
Qualified Pension [Member] | Quoted Prices In Active Markets [Member] | Large Cap Core Index [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	12,023,000	10,260,000	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	12,023,000	10,260,000	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	12,023,000	10,260,000	'
Qualified Pension [Member] | Quoted Prices In Active Markets [Member] | Large Cap Value [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	16,908,000	10,427,000	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	16,908,000	10,427,000	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	16,908,000	10,427,000	'
Qualified Pension [Member] | Quoted Prices In Active Markets [Member] | Large Cap Growth [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	17,823,000	15,252,000	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	17,823,000	15,252,000	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	17,823,000	15,252,000	'
Qualified Pension [Member] | Quoted Prices In Active Markets [Member] | Small Cap Value [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	30,831,000	26,335,000	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	30,831,000	26,335,000	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	30,831,000	26,335,000	'
Qualified Pension [Member] | Quoted Prices In Active Markets [Member] | Common Trust Fund International Value [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	0	'	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	0	'	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	0	'	'
Qualified Pension [Member] | Quoted Prices In Active Markets [Member] | International Value [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	'	14,376,000	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	'	14,376,000	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	'	14,376,000	'
Qualified Pension [Member] | Quoted Prices In Active Markets [Member] | Common Trust Fund International Growth [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	0	0	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	0	0	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	0	0	'
Qualified Pension [Member] | Quoted Prices In Active Markets [Member] | Global Reit [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	15,042,000	16,252,000	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	15,042,000	16,252,000	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	15,042,000	16,252,000	'
Qualified Pension [Member] | Quoted Prices In Active Markets [Member] | Hedge Funds [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	0	0	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	0	0	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	0	0	'
Qualified Pension [Member] | Quoted Prices In Active Markets [Member] | Private Equity Funds [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	0	0	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	0	0	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	0	0	'
Qualified Pension [Member] | Quoted Prices In Active Markets [Member] | Commodities [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	0	0	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	0	0	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	0	0	'
Qualified Pension [Member] | Significant Other Observable Inputs [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	183,123,000	156,793,000	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Weighted Average Asset Allocations	'	61.00%	58.00%	'
Defined Benefit Plan Fair Value Of Plan Assets	'	183,123,000	156,793,000	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	183,123,000	156,793,000	'
Qualified Pension [Member] | Significant Other Observable Inputs [Member] | Cash [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	156,000	0	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	156,000	0	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	156,000	0	'
Qualified Pension [Member] | Significant Other Observable Inputs [Member] | US Treasuries [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	24,078,000	17,544,000	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	24,078,000	17,544,000	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	24,078,000	17,544,000	'
Qualified Pension [Member] | Significant Other Observable Inputs [Member] | Long Duration Bonds [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	34,041,000	63,565,000	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	34,041,000	63,565,000	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	34,041,000	63,565,000	'
Qualified Pension [Member] | Significant Other Observable Inputs [Member] | Corporate Bonds [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	42,701,000	26,368,000	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	42,701,000	26,368,000	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	42,701,000	26,368,000	'
Qualified Pension [Member] | Significant Other Observable Inputs [Member] | High Yield Bonds [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	0	0	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	0	0	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	0	0	'
Qualified Pension [Member] | Significant Other Observable Inputs [Member] | Collateralized Mortgage Backed Securities [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	1,098,000	1,513,000	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	1,098,000	1,513,000	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	1,098,000	1,513,000	'
Qualified Pension [Member] | Significant Other Observable Inputs [Member] | Municipals [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	0	345,000	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	0	345,000	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	0	345,000	'
Qualified Pension [Member] | Significant Other Observable Inputs [Member] | Derivatives [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	-17,000	-86,000	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	-17,000	-86,000	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	-17,000	-86,000	'
Qualified Pension [Member] | Significant Other Observable Inputs [Member] | Large Cap Core Index [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	0	0	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	0	0	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	0	0	'
Qualified Pension [Member] | Significant Other Observable Inputs [Member] | Large Cap Value [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	0	0	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	0	0	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	0	0	'
Qualified Pension [Member] | Significant Other Observable Inputs [Member] | Large Cap Growth [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	0	0	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	0	0	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	0	0	'
Qualified Pension [Member] | Significant Other Observable Inputs [Member] | Small Cap Value [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	0	0	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	0	0	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	0	0	'
Qualified Pension [Member] | Significant Other Observable Inputs [Member] | Common Trust Fund International Value [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	24,460,000	'	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	24,460,000	'	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	24,460,000	'	'
Qualified Pension [Member] | Significant Other Observable Inputs [Member] | International Value [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	'	0	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	'	0	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	'	0	'
Qualified Pension [Member] | Significant Other Observable Inputs [Member] | Common Trust Fund International Growth [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	27,270,000	18,678,000	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	27,270,000	18,678,000	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	27,270,000	18,678,000	'
Qualified Pension [Member] | Significant Other Observable Inputs [Member] | Global Reit [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	0	0	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	0	0	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	0	0	'
Qualified Pension [Member] | Significant Other Observable Inputs [Member] | Hedge Funds [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	18,571,000	16,995,000	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	18,571,000	16,995,000	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	18,571,000	16,995,000	'
Qualified Pension [Member] | Significant Other Observable Inputs [Member] | Private Equity Funds [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	0	0	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	0	0	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	0	0	'
Qualified Pension [Member] | Significant Other Observable Inputs [Member] | Commodities [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	10,765,000	11,871,000	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	10,765,000	11,871,000	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	10,765,000	11,871,000	'
Qualified Pension [Member] | Significant Unobservable Inputs [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at beginning of year	'	3,522,000	16,604,000	'
Fair value at end of year	'	4,659,000	3,522,000	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Weighted Average Asset Allocations	'	2.00%	1.00%	'
Defined Benefit Plan Fair Value Of Plan Assets	'	4,659,000	3,522,000	'
Reconciliation Of Plan Assets Classified As Level 3 Roll Forward	'	'	'	'
Fair value at beginning of year	'	3,522,000	16,604,000	'
Actual return on plan assets:	'	'	'	'
Relating to assets still held at the reporting date	'	116,000	13,000	'
Relating to assets sold during the period	'	61,000	145,000	'
Purchases, sales and settlements (net)	'	960,000	1,439,000	'
Transfer in/out of Level 3	'	0	-14,679,000	'
Fair value at end of year	'	4,659,000	3,522,000	'
Qualified Pension [Member] | Significant Unobservable Inputs [Member] | Cash [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	0	0	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	0	0	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	0	0	'
Qualified Pension [Member] | Significant Unobservable Inputs [Member] | US Treasuries [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	0	0	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	0	0	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	0	0	'
Qualified Pension [Member] | Significant Unobservable Inputs [Member] | Long Duration Bonds [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	0	0	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	0	0	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	0	0	'
Qualified Pension [Member] | Significant Unobservable Inputs [Member] | Corporate Bonds [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	0	0	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	0	0	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	0	0	'
Qualified Pension [Member] | Significant Unobservable Inputs [Member] | High Yield Bonds [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	0	0	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	0	0	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	0	0	'
Qualified Pension [Member] | Significant Unobservable Inputs [Member] | Collateralized Mortgage Backed Securities [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	0	0	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	0	0	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	0	0	'
Qualified Pension [Member] | Significant Unobservable Inputs [Member] | Municipals [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	0	0	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	0	0	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	0	0	'
Qualified Pension [Member] | Significant Unobservable Inputs [Member] | Derivatives [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	0	0	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	0	0	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	0	0	'
Qualified Pension [Member] | Significant Unobservable Inputs [Member] | Large Cap Core Index [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	0	0	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	0	0	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	0	0	'
Qualified Pension [Member] | Significant Unobservable Inputs [Member] | Large Cap Value [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	0	0	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	0	0	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	0	0	'
Qualified Pension [Member] | Significant Unobservable Inputs [Member] | Large Cap Growth [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	0	0	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	0	0	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	0	0	'
Qualified Pension [Member] | Significant Unobservable Inputs [Member] | Small Cap Value [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	0	0	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	0	0	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	0	0	'
Qualified Pension [Member] | Significant Unobservable Inputs [Member] | Common Trust Fund International Value [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	0	'	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	0	'	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	0	'	'
Qualified Pension [Member] | Significant Unobservable Inputs [Member] | International Value [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	'	0	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	'	0	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	'	0	'
Qualified Pension [Member] | Significant Unobservable Inputs [Member] | Common Trust Fund International Growth [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	0	0	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	0	0	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	0	0	'
Qualified Pension [Member] | Significant Unobservable Inputs [Member] | Global Reit [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	0	0	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	0	0	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	0	0	'
Qualified Pension [Member] | Significant Unobservable Inputs [Member] | Hedge Funds [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at beginning of year	'	0	6,207,000	'
Fair value at end of year	'	0	0	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	0	0	'
Reconciliation Of Plan Assets Classified As Level 3 Roll Forward	'	'	'	'
Fair value at beginning of year	'	0	6,207,000	'
Actual return on plan assets:	'	'	'	'
Relating to assets still held at the reporting date	'	0	0	'
Relating to assets sold during the period	'	0	0	'
Purchases, sales and settlements (net)	'	0	0	'
Transfer in/out of Level 3	'	0	-6,207,000	'
Fair value at end of year	'	0	0	'
Qualified Pension [Member] | Significant Unobservable Inputs [Member] | Private Equity Funds [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at beginning of year	'	3,522,000	1,925,000	'
Fair value at end of year	'	4,659,000	3,522,000	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	4,659,000	3,522,000	'
Reconciliation Of Plan Assets Classified As Level 3 Roll Forward	'	'	'	'
Fair value at beginning of year	'	3,522,000	1,925,000	'
Actual return on plan assets:	'	'	'	'
Relating to assets still held at the reporting date	'	116,000	13,000	'
Relating to assets sold during the period	'	61,000	145,000	'
Purchases, sales and settlements (net)	'	960,000	1,439,000	'
Transfer in/out of Level 3	'	0	0	'
Fair value at end of year	'	4,659,000	3,522,000	'
Qualified Pension [Member] | Significant Unobservable Inputs [Member] | Commodities [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at beginning of year	'	0	8,472,000	'
Fair value at end of year	'	0	0	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	0	0	'
Reconciliation Of Plan Assets Classified As Level 3 Roll Forward	'	'	'	'
Fair value at beginning of year	'	0	8,472,000	'
Actual return on plan assets:	'	'	'	'
Relating to assets still held at the reporting date	'	0	0	'
Relating to assets sold during the period	'	0	0	'
Purchases, sales and settlements (net)	'	0	0	'
Transfer in/out of Level 3	'	0	-8,472,000	'
Fair value at end of year	'	0	0	'
Non Qualified Pension [Member]	'	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'	'
Estimated Future Employee Contributions Next Fiscal Year	'	444,000	'	'
Reconciliation Of Changes In Plan Benefit Obligations And Fair Value Of Assets [Abstract]	'	'	'	'
Accumulated Benefit Obligation At Year End	'	4,736,000	5,569,000	'
Change In Benefit Obligation	'	'	'	'
Obligation at beginning of year	'	5,569,000	5,219,000	'
Service cost	'	0	39,000	45,000
Interest cost	'	157,000	203,000	209,000
Actuarial (gain) loss	'	-540,000	629,000	'
Participant contributions	'	0	0	'
Administrative expenses	'	0	0	'
Benefit payments	'	-450,000	-521,000	'
Obligation at end of year	'	4,736,000	5,569,000	5,219,000
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at beginning of year	'	0	0	'
Actual return on plan assets	'	0	0	'
Employer contributions	'	450,000	521,000	'
Participant contributions	'	0	0	'
Administrative expenses	'	0	0	'
Benefit payments	'	-450,000	-521,000	'
Fair value at end of year	'	0	0	0
Funded status at year end - (under) over	'	-4,736,000	-5,569,000	'
Noncurrent assets	'	0	0	'
Current liabilities	'	-445,000	-502,000	'
Noncurrent liabilities	'	-4,291,000	-5,067,000	'
Net amount recognized	'	-4,736,000	-5,569,000	'
Amounts Not Yet Recognized as a Component of Cost and Recognized in a Deferred Regulatory Account	'	'	'	'
Unrecognized transition obligation	'	0	0	'
Unrecognized prior service (cost) credit	'	-196,000	-277,000	'
Unrecognized actuarial loss	'	-820,000	-1,521,000	'
Cumulative Employer Contribution In Excess Of Cost	'	-3,720,000	-3,771,000	'
Benefit Obligation Weighted Average Assumptions [Abstract]	'	'	'	'
Discount Rate	'	3.98%	2.95%	'
Net Periodic Benefits Cost Weighted Average Assumptions [Abstract]	'	'	'	'
Discount Rate	'	2.95%	4.10%	4.37%
Defined Benefit Plan Estimated Future Benefit Payments Abstract	'	'	'	'
2014	'	444,000	'	'
2015	'	458,000	'	'
2016	'	434,000	'	'
2017	'	410,000	'	'
2018	'	383,000	'	'
2019 - 2023	'	1,890,000	'	'
Defined Benefit Plan Net Periodic Benefit Cost Abstract	'	'	'	'
Service cost	'	0	39,000	45,000
Interest cost	'	157,000	203,000	209,000
Expected return on plan assets	'	0	0	0
Amortization of transition obligation	'	0	0	0
Amortization of prior service cost (credit)	'	81,000	81,000	20,000
Amortization of net loss	'	161,000	49,000	41,000
Net periodic benefit (income) cost	'	399,000	372,000	315,000
Other Changes In Plan Assets And Benefit Obligatin Recognized Through Regulatory Asset Or Liability [Abstract]	'	'	'	'
Prior service cost	'	0	0	290,000
Net loss (gain)	'	-540,000	629,000	130,000
Amounts Recognized As Component Of Net Periodic Benefit Cost [Abstract]	'	'	'	'
Amortization of transition obligation	'	0	0	0
Amortization of net loss	'	161,000	49,000	41,000
Amortization of prior service cost (credit)	'	81,000	81,000	20,000
Total recognized in regulatory asset (liability)	'	-782,000	499,000	359,000
Total Recognized In Net Periodic Benefit Cost And Regulatory Asset (Liability)	'	-383,000	871,000	674,000
Estimated Amortization And Expected Refunds [Abstract]	'	'	'	'
Amortization of unrecognized prior service cost (credit)	'	81,000	'	'
Amortization of unrecognized actuarial loss	'	47,000	'	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	0	0	0
Reconciliation Of Plan Assets Classified As Level 3 Roll Forward	'	'	'	'
Fair value at beginning of year	'	0	0	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	0	0	0
Non Qualified Pension [Member] | Amounts Not Yet Recognized As Component Of Pension Liability [Member]	'	'	'	'
Amounts Not Yet Recognized as a Component of Cost and Recognized in a Deferred Regulatory Account	'	'	'	'
Regulatory asset	'	-1,016,000	-1,798,000	'
Other Benefits [Member]	'	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'	'
Defined Benefit Plans General Information	'	'We provide certain postretirement health care and life insurance benefits to eligible retirees. The liability associated with such benefits is funded in irrevocable trust funds that can only be used to pay the benefits. Employees are first eligible to retire and receive these benefits at age 55 with ten or more years of service after the age of 45. Employees who met this requirement in 1993 or who retired prior to 1993 are in a “grandfathered” group for whom we pay the full cost of the retiree’s coverage. Retirees not in the grandfathered group have a portion of the cost of retiree coverage paid by us, subject to certain annual contribution limits. Retirees are responsible for the full cost of dependent coverage. Effective January 1, 2008, new employees have to complete ten years of service after age 50 to be eligible for benefits, and no benefits are provided to those employees after age 65 when they are automatically eligible for Medicare benefits to cover health costs. Our OPEB plan includes a defined dollar benefit to pay the premiums for Medicare Part D. Employees who meet the eligibility requirements to retire also receive a life insurance benefit. For employees who retire after July 1, 2005, this benefit is $15,000. The life insurance amount for employees who retired prior to this date was calculated as a percentage of their basic life insurance prior to retirement.	'	'
Estimated Future Employee Contributions Next Fiscal Year	'	1,500,000	'	'
Change In Benefit Obligation	'	'	'	'
Obligation at beginning of year	'	34,830,000	31,900,000	'
Service cost	'	1,327,000	1,387,000	1,398,000
Interest cost	'	1,130,000	1,347,000	1,495,000
Actuarial (gain) loss	'	-1,094,000	2,630,000	'
Participant contributions	'	641,000	788,000	'
Administrative expenses	'	0	0	'
Benefit payments	'	-3,156,000	-3,222,000	'
Obligation at end of year	'	33,678,000	34,830,000	31,900,000
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at beginning of year	'	23,663,000	22,045,000	'
Actual return on plan assets	'	2,848,000	1,972,000	'
Employer contributions	'	1,965,000	2,080,000	'
Participant contributions	'	641,000	788,000	'
Administrative expenses	'	0	0	'
Benefit payments	'	-3,156,000	-3,222,000	'
Fair value at end of year	'	25,961,000	23,663,000	22,045,000
Funded status at year end - (under) over	'	-7,717,000	-11,167,000	'
Noncurrent assets	'	0	0	'
Current liabilities	'	0	0	'
Noncurrent liabilities	'	-7,717,000	-11,167,000	'
Net amount recognized	'	-7,717,000	-11,167,000	'
Amounts Not Yet Recognized as a Component of Cost and Recognized in a Deferred Regulatory Account	'	'	'	'
Unrecognized transition obligation	'	0	-667,000	'
Unrecognized prior service (cost) credit	'	0	0	'
Unrecognized actuarial loss	'	-354,000	-2,633,000	'
Cumulative Employer Contribution In Excess Of Cost	'	-7,363,000	-7,867,000	'
Benefit Obligation Weighted Average Assumptions [Abstract]	'	'	'	'
Discount Rate	'	4.44%	3.34%	'
Net Periodic Benefits Cost Weighted Average Assumptions [Abstract]	'	'	'	'
Discount Rate	'	3.34%	4.36%	4.85%
Expected Long Term Rate Of Return On Plan Assets	'	8.00%	8.00%	8.00%
Defined Benefit Plan Estimated Future Benefit Payments Abstract	'	'	'	'
2014	'	2,140,000	'	'
2015	'	2,262,000	'	'
2016	'	2,322,000	'	'
2017	'	2,417,000	'	'
2018	'	2,507,000	'	'
2019 - 2023	'	13,640,000	'	'
Assumed Health Care Cost Rate Trends Abstract	'	'	'	'
Health Care Cost Trend Rate Assumed For Next Fiscal Year	'	7.40%	7.50%	'
Ultimate Health Care Cost Trend Rate	'	5.00%	5.00%	'
Year That Rate Reaches Ultimate Trend Rate	'	'2027	'2027	'
Effect Of Health Care Cost Trend Rate Assumptions [Abstract]	'	'	'	'
Effect of One Percentage Point Increase on Service and Interest Cost Components	'	21,000	'	'
Effect of One Percentage Point Decrease on Service and Interest Cost Components	'	27,000	'	'
Effect Of One Percentage Point Increase on Postretirement Benefit Obligation	'	690,000	'	'
Effect of One Percentage Point Decrease on Postretirement Benefit Obligation	'	699,000	'	'
Defined Benefit Plan Net Periodic Benefit Cost Abstract	'	'	'	'
Service cost	'	1,327,000	1,387,000	1,398,000
Interest cost	'	1,130,000	1,347,000	1,495,000
Expected return on plan assets	'	-1,663,000	-1,551,000	-1,534,000
Amortization of transition obligation	'	667,000	667,000	667,000
Amortization of prior service cost (credit)	'	0	0	0
Amortization of net loss	'	0	0	0
Net periodic benefit (income) cost	'	1,461,000	1,850,000	2,026,000
Other Changes In Plan Assets And Benefit Obligatin Recognized Through Regulatory Asset Or Liability [Abstract]	'	'	'	'
Prior service cost	'	0	0	0
Net loss (gain)	'	-2,278,000	2,209,000	415,000
Amounts Recognized As Component Of Net Periodic Benefit Cost [Abstract]	'	'	'	'
Amortization of transition obligation	'	667,000	667,000	667,000
Amortization of net loss	'	0	0	0
Amortization of prior service cost (credit)	'	0	0	0
Total recognized in regulatory asset (liability)	'	-2,945,000	1,542,000	-252,000
Total Recognized In Net Periodic Benefit Cost And Regulatory Asset (Liability)	'	-1,484,000	3,392,000	1,774,000
Estimated Amortization And Expected Refunds [Abstract]	'	'	'	'
Amortization of unrecognized prior service cost (credit)	'	0	'	'
Amortization of unrecognized actuarial loss	'	0	'	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Weighted Average Asset Allocations	'	100.00%	100.00%	'
Defined Benefit Plan Fair Value Of Plan Assets	'	25,961,000	23,663,000	22,045,000
Reconciliation Of Plan Assets Classified As Level 3 Roll Forward	'	'	'	'
Fair value at beginning of year	'	23,663,000	22,045,000	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	25,961,000	23,663,000	22,045,000
Standard Eligibility Age For Defined Benefit Plan	'45 years	'50 years	'	'
Service Required For Eligibility In Defined Benefit Plan	'10 years	'10 years	'	'
Plan Vesting Period Defined Benefit Plan	'	'65 years	'	'
Benefits Provided After Employee Is Eligible for Medicare Benefits	'	0	'	'
Term Life Insurance Per Individual Benefit Provided By Employer	'	15,000	'	'
Other Benefits [Member] | Amounts Not Yet Recognized As Component Of Pension Liability [Member]	'	'	'	'
Amounts Not Yet Recognized as a Component of Cost and Recognized in a Deferred Regulatory Account	'	'	'	'
Regulatory asset	'	-354,000	-3,300,000	'
Other Benefits [Member] | Cash [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at beginning of year	'	926,000	'	'
Fair value at end of year	'	982,000	'	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Weighted Average Asset Allocations	'	4.00%	4.00%	'
Target Plan Asset Allocations	'	3.00%	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	982,000	'	'
Reconciliation Of Plan Assets Classified As Level 3 Roll Forward	'	'	'	'
Fair value at beginning of year	'	926,000	'	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	982,000	'	'
Other Benefits [Member] | Total Fixed Income Securities [Member]	'	'	'	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Weighted Average Asset Allocations	'	46.00%	46.00%	'
Target Plan Asset Allocations	'	45.00%	'	'
Other Benefits [Member] | US Treasuries [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	2,582,000	2,345,000	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Weighted Average Asset Allocations	'	10.00%	10.00%	'
Defined Benefit Plan Fair Value Of Plan Assets	'	2,582,000	2,345,000	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	2,582,000	2,345,000	'
Other Benefits [Member] | Corporate Bonds [Member]	'	'	'	'
Amounts Not Yet Recognized as a Component of Cost and Recognized in a Deferred Regulatory Account	'	'	'	'
Investment Maturity Date	'	'within 10 years	'	'
Other Benefits [Member] | Corporate Bonds Other Fixed Income Securities [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	9,232,000	8,474,000	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Weighted Average Asset Allocations	'	36.00%	36.00%	'
Defined Benefit Plan Fair Value Of Plan Assets	'	9,232,000	8,474,000	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	9,232,000	8,474,000	'
Other Benefits [Member] | High Yield Bonds [Member]	'	'	'	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Target Plan Asset Allocations	'	5.00%	'	'
Other Benefits [Member] | Total Equity Securities	'	'	'	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Weighted Average Asset Allocations	'	45.00%	45.00%	'
Target Plan Asset Allocations	'	47.00%	'	'
Other Benefits [Member] | Large Cap Value [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	1,327,000	1,221,000	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Weighted Average Asset Allocations	'	5.00%	5.00%	'
Defined Benefit Plan Fair Value Of Plan Assets	'	1,327,000	1,221,000	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	1,327,000	1,221,000	'
Other Benefits [Member] | Large Cap Growth [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	1,352,000	1,149,000	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Weighted Average Asset Allocations	'	5.00%	5.00%	'
Defined Benefit Plan Fair Value Of Plan Assets	'	1,352,000	1,149,000	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	1,352,000	1,149,000	'
Other Benefits [Member] | Small Cap Value [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	1,331,000	1,177,000	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Weighted Average Asset Allocations	'	5.00%	5.00%	'
Defined Benefit Plan Fair Value Of Plan Assets	'	1,331,000	1,177,000	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	1,331,000	1,177,000	'
Other Benefits [Member] | Small Cap Growth [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	1,313,000	1,155,000	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Weighted Average Asset Allocations	'	5.00%	5.00%	'
Defined Benefit Plan Fair Value Of Plan Assets	'	1,313,000	1,155,000	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	1,313,000	1,155,000	'
Other Benefits [Member] | Large Cap Index [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	2,384,000	2,148,000	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Weighted Average Asset Allocations	'	9.00%	9.00%	'
Defined Benefit Plan Fair Value Of Plan Assets	'	2,384,000	2,148,000	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	2,384,000	2,148,000	'
Other Benefits [Member] | International Blend [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	4,206,000	3,907,000	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Weighted Average Asset Allocations	'	16.00%	16.00%	'
Defined Benefit Plan Fair Value Of Plan Assets	'	4,206,000	3,907,000	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	4,206,000	3,907,000	'
Other Benefits [Member] | Total Real Estate [Member]	'	'	'	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Weighted Average Asset Allocations	'	5.00%	5.00%	'
Other Benefits [Member] | Global Reit [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at beginning of year	'	1,161,000	'	'
Fair value at end of year	'	1,252,000	'	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Weighted Average Asset Allocations	'	5.00%	5.00%	'
Target Plan Asset Allocations	'	5.00%	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	1,252,000	'	'
Reconciliation Of Plan Assets Classified As Level 3 Roll Forward	'	'	'	'
Fair value at beginning of year	'	1,161,000	'	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	1,252,000	'	'
Other Benefits [Member] | Total Investments [Member]	'	'	'	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Weighted Average Asset Allocations	'	100.00%	100.00%	'
Other Benefits [Member] | Quoted Prices In Active Markets [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	25,961,000	23,663,000	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Weighted Average Asset Allocations	'	100.00%	100.00%	'
Defined Benefit Plan Fair Value Of Plan Assets	'	25,961,000	23,663,000	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	25,961,000	23,663,000	'
Other Benefits [Member] | Quoted Prices In Active Markets [Member] | Cash [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	982,000	926,000	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	982,000	926,000	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	982,000	926,000	'
Other Benefits [Member] | Quoted Prices In Active Markets [Member] | US Treasuries [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	2,582,000	2,345,000	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	2,582,000	2,345,000	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	2,582,000	2,345,000	'
Other Benefits [Member] | Quoted Prices In Active Markets [Member] | Corporate Bonds Other Fixed Income Securities [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	9,232,000	8,474,000	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	9,232,000	8,474,000	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	9,232,000	8,474,000	'
Other Benefits [Member] | Quoted Prices In Active Markets [Member] | Large Cap Value [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	1,327,000	1,221,000	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	1,327,000	1,221,000	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	1,327,000	1,221,000	'
Other Benefits [Member] | Quoted Prices In Active Markets [Member] | Large Cap Growth [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	1,352,000	1,149,000	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	1,352,000	1,149,000	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	1,352,000	1,149,000	'
Other Benefits [Member] | Quoted Prices In Active Markets [Member] | Small Cap Value [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	1,331,000	1,177,000	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	1,331,000	1,177,000	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	1,331,000	1,177,000	'
Other Benefits [Member] | Quoted Prices In Active Markets [Member] | Small Cap Growth [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	1,313,000	1,155,000	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	1,313,000	1,155,000	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	1,313,000	1,155,000	'
Other Benefits [Member] | Quoted Prices In Active Markets [Member] | Large Cap Index [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	2,384,000	2,148,000	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	2,384,000	2,148,000	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	2,384,000	2,148,000	'
Other Benefits [Member] | Quoted Prices In Active Markets [Member] | International Blend [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	4,206,000	3,907,000	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	4,206,000	3,907,000	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	4,206,000	3,907,000	'
Other Benefits [Member] | Quoted Prices In Active Markets [Member] | Global Reit [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	1,252,000	1,161,000	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	1,252,000	1,161,000	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	1,252,000	1,161,000	'
Other Benefits [Member] | Significant Other Observable Inputs [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	0	0	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Weighted Average Asset Allocations	'	0.00%	0.00%	'
Defined Benefit Plan Fair Value Of Plan Assets	'	0	0	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	0	0	'
Other Benefits [Member] | Significant Other Observable Inputs [Member] | Cash [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	0	0	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	0	0	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	0	0	'
Other Benefits [Member] | Significant Other Observable Inputs [Member] | US Treasuries [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	0	0	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	0	0	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	0	0	'
Other Benefits [Member] | Significant Other Observable Inputs [Member] | Corporate Bonds Other Fixed Income Securities [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	0	0	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	0	0	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	0	0	'
Other Benefits [Member] | Significant Other Observable Inputs [Member] | Large Cap Value [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	0	0	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	0	0	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	0	0	'
Other Benefits [Member] | Significant Other Observable Inputs [Member] | Large Cap Growth [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	0	0	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	0	0	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	0	0	'
Other Benefits [Member] | Significant Other Observable Inputs [Member] | Small Cap Value [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	0	0	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	0	0	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	0	0	'
Other Benefits [Member] | Significant Other Observable Inputs [Member] | Small Cap Growth [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	0	0	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	0	0	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	0	0	'
Other Benefits [Member] | Significant Other Observable Inputs [Member] | Large Cap Index [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	0	0	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	0	0	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	0	0	'
Other Benefits [Member] | Significant Other Observable Inputs [Member] | International Blend [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	0	0	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	0	0	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	0	0	'
Other Benefits [Member] | Significant Other Observable Inputs [Member] | Global Reit [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	0	0	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	0	0	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	0	0	'
Other Benefits [Member] | Significant Unobservable Inputs [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	0	0	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Weighted Average Asset Allocations	'	0.00%	0.00%	'
Defined Benefit Plan Fair Value Of Plan Assets	'	0	0	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	0	0	'
Other Benefits [Member] | Significant Unobservable Inputs [Member] | Cash [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	0	0	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	0	0	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	0	0	'
Other Benefits [Member] | Significant Unobservable Inputs [Member] | US Treasuries [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	0	0	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	0	0	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	0	0	'
Other Benefits [Member] | Significant Unobservable Inputs [Member] | Corporate Bonds Other Fixed Income Securities [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	0	0	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	0	0	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	0	0	'
Other Benefits [Member] | Significant Unobservable Inputs [Member] | Large Cap Value [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	0	0	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	0	0	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	0	0	'
Other Benefits [Member] | Significant Unobservable Inputs [Member] | Large Cap Growth [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	0	0	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	0	0	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	0	0	'
Other Benefits [Member] | Significant Unobservable Inputs [Member] | Small Cap Value [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	0	0	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	0	0	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	0	0	'
Other Benefits [Member] | Significant Unobservable Inputs [Member] | Small Cap Growth [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	0	0	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	0	0	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	0	0	'
Other Benefits [Member] | Significant Unobservable Inputs [Member] | Large Cap Index [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	0	0	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	0	0	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	0	0	'
Other Benefits [Member] | Significant Unobservable Inputs [Member] | International Blend [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	0	0	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	0	0	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	0	0	'
Other Benefits [Member] | Significant Unobservable Inputs [Member] | Global Reit [Member]	'	'	'	'
Defined Benefit Plan Change In Fair Value Of Plan Assets Roll Forward	'	'	'	'
Fair value at end of year	'	0	0	'
Plan Assets Fair Value Hierarchy [Abstract]	'	'	'	'
Defined Benefit Plan Fair Value Of Plan Assets	'	0	0	'
Actual return on plan assets:	'	'	'	'
Fair value at end of year	'	0	0	'
NCNG SERP [Member]	'	'	'	'
Net Periodic Benefits Cost Weighted Average Assumptions [Abstract]	'	'	'	'
Discount Rate	'	3.89%	'	'
Directors SERP [Member]	'	'	'	'
Net Periodic Benefits Cost Weighted Average Assumptions [Abstract]	'	'	'	'
Discount Rate	'	4.09%	'	'
Piedmont SERP [Member]	'	'	'	'
Net Periodic Benefits Cost Weighted Average Assumptions [Abstract]	'	'	'	'
Discount Rate	'	3.31%	'	'
Pension [Member]	'	'	'	'
Amounts Not Yet Recognized as a Component of Cost and Recognized in a Deferred Regulatory Account	'	'	'	'
Defined Benefit Plan Measurement Date	'	'31-Oct	'	'
Defined Benefit Plan Actuarial Gains And Losses Amortization Corridor	'	'5 years	'	'
Gains And Losses Amortized In Excess Of Percentage	'	10.00%	'	'
Defined Benefit Pension Plan Funding Target	'	100.00%	'	'
Supplemental Executive Retirement Plans [Member]	'	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'	'
Defined Benefit Plans General Information	'	'We have pension liabilities related to supplemental executive retirement plans (SERPs) for certain former employees, non-employee directors or surviving spouses. There are no assets related to these SERPs, and no additional benefits accrue to the participants. Payments to the participants are made from operating funds during the year.	'	'
Actual return on plan assets:	'	'	'	'
Assets for Participant Benefits	'	0	'	'
Officers and Director-Level Employees Life Insurance [Member]	'	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'	'
Defined Benefit Plans General Information	'	'We also provide a term life insurance benefit equal to $200,000 to all officers and director-level employees for which we bear the cost of the policies.	'	'
Actual return on plan assets:	'	'	'	'
Term Life Insurance Per Individual Benefit Provided By Employer	'	$200,000	'	'
Certain Officers Vice President And Above Life Insurance [Member]	'	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'	'
Defined Benefit Plans General Information	'	'We provide term life insurance policies for certain officers at the vice president level and above who were former participants in a terminated SERP; the level of the insurance benefit is dependent upon the level of the benefit provided under the terminated SERP. These life insurance policies are owned exclusively by each officer. Premiums on these policies are paid and expensed.	'	'

Employee_Share_Based_Plans_Det

Employee Share Based Plans (Details) (USD $)

12 Months Ended

37 Months Ended

1 Months Ended

12 Months Ended

60 Months Ended

Oct. 31, 2013

Oct. 31, 2012

Oct. 31, 2011

Oct. 31, 2013

Oct. 31, 2013

Oct. 31, 2013

Oct. 31, 2013

Oct. 31, 2013

Oct. 31, 2013

Oct. 31, 2013

Oct. 31, 2013

Dec. 31, 2013

Dec. 31, 2011

Oct. 31, 2013

Dec. 15, 2016

Stock Compensation Plan [Member]

Long Term Incentive Plan Two Performance Measures [Member]

Long Term Incentive Plan Two Performance Measures [Member]

Long Term Incentive Plan Two Performance Measures [Member]

Long Term Incentive Plan Three Performance Measures [Member]

Long Term Incentive Plan Three Performance Measures [Member]

Long Term Incentive Plan Three Performance Measures [Member]

Long Term Incentive Plan Three Performance Measures [Member]

Retention Stock Unit Award Eligible Officers [Member]

Retention Stock Unit Award President And Cheif Executive Officer [Member]

Retention Stock Unit Award President And Cheif Executive Officer [Member]

Retention Stock Unit Award President And Cheif Executive Officer [Member]

Stock Compensation Plan [Member]

Stock Compensation Plan [Member]

Stock Compensation Plan [Member]

Stock Compensation Plan [Member]

Stock Compensation Plan [Member]

Stock Compensation Plan [Member]

Stock Compensation Plan [Member]

Stock Compensation Plan [Member]

Stock Compensation Plan [Member]

Stock Compensation Plan [Member]

Stock Compensation Plan [Member]

EPS Performance [Member]

Annual Shareholder Return [Member]

EPS Performance [Member]

Annual Shareholder Return [Member]

Return On Equity [Member]

Employee Share Based Plans Details [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Unvested Shares Issued To CEO

'

'

'

'

'

'

'

'

'

'

'

'

64,700

'

'

Incentive Compensation Plan Percentage Of Common Stock Vested

'

'

'

'

'

'

'

'

'

'

'

'

'

'In accordance with the vesting schedule, 20% of the units vest on December 15, 2014, 30% of the units vest on December 15, 2015 and 50% of the units vest on December 15, 2016.

'

Compensation Expense

$4,526,000

$5,730,000

$2,604,000

'

'

'

'

'

'

'

'

'

'

'

'

Tax Benefit

1,538,000

2,080,000

673,000

'

'

'

'

'

'

'

'

'

'

'

'

Liability

11,098,000

10,631,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Incentive Compensation Plan Expected Payout In One Year

4,071,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Incentive Compensation Plan Expected Payout In Two Years

4,290,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Incentive Compensation Plan Expected Payout In Three Years

2,290,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Incentive Compensation Plan Expected Payout In Four Years

$446,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Employee Stock Purchase Plan Exercise Price As A Percentage Of Fair Market Value

95.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Share Based Compensation Arrangement By Share Based Payment Award Description

'Under our shareholder approved ICP, eligible officers and other participants are awarded units that pay out depending upon the level of performance achieved by Piedmont during three-year incentive plan performance periods. Distribution of those awards may be made in the form of shares of common stock and withholdings for payment of applicable taxes on the compensation. These plans require that a minimum threshold performance level be achieved in order for any award to be distributed. Also under our approved ICP, 64,700 unvested retention stock units were granted to our President and Chief Executive Officer in December 2011. At the time of distribution of awards under the ICP, the number of shares issuable is reduced by the withholdings for payment of applicable income taxes for each participant. The participant may elect income tax withholdings at or above the minimum statutory withholding requirements. The maximum withholdings allowed is 50%.

'

'

'

'

'

'

'

'

'

'

'

'

'In December 2010, a long-term retention stock unit award under the ICP (where a stock unit equals one share of our common stock upon vesting) was approved for eligible officers and other participants to support our succession planning and retention strategies. This retention stock unit award will vest for participants who have met the retention requirements at the end of a three-year period ending in December 2013 in the form of shares of common stock and withholdings for payment of applicable taxes on the compensation. The Compensation Committee of our Board of Directors has the discretion to accelerate the vesting of all or a portion of a participant’s units.

'

Share Based Compensation Arrangement By Share Based Payment Award Award Requisite Service Period

'

'

'

'

'

'

'

'

'

'

'

'3 years

'

'

'5 years

Share Based Compensation Arrangement By Share Based Payment Award Terms Of Award

'

'

'

'

'For each of these performance periods, awards will be based on achievement relative to a target annual compounded increase in basic EPS and the achievement of total shareholder returns relative to a group of peer companies that are domiciled in the United States, publicly traded in the U.S. energy industry with a primary focus on natural gas distribution and transmission businesses in multi-state territories and have similar annual revenues and market capitalization to ours, with each measure being weighted at 50%.

'

'

'The plan with the performance period ending October 31, 2015 (2015 plan) has an additional performance measure of actual average return on equity compared to the weighted average return on equity allowed by our regulatory commissions. The weighting of the units awarded under the 2015 plan is based on EPS at 37.5%, total shareholder return at 37.5 % and return on equity at 25% of the total units awarded.

'

'

'

'

'

'During the five-year vesting period, any dividend equivalents will accrue on these stock units and be converted into additional units at the same rate and based on the closing price on the same payment date as dividends on our common stock. The stock units will vest, payable in the form of shares of common stock and withholdings for payment of applicable taxes on the compensation, over a five-year period only if he is an employee on each vesting date.

'

Number Of Incentive Compensation Plan Awards

'

'

'

3

'

'

'

'

'

'

'

'

'

'

'

Number Of Performance Periods Under Icp Plans

3

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Maximum Statutory Withholdings Allowed

50.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Allocation Of Performance Units

'

'

'

'

'

50.00%

50.00%

'

37.50%

37.50%

25.00%

'

'

'

'

Income_Taxes_Details

Income Taxes (Details) (USD $)

12 Months Ended

0 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

Oct. 31, 2013

Oct. 31, 2012

Oct. 31, 2011

Oct. 31, 2013

Jan. 01, 2015

Jan. 02, 2014

Dec. 31, 2013

Oct. 31, 2013

Oct. 31, 2013

Oct. 31, 2012

Oct. 31, 2011

Oct. 31, 2013

Oct. 31, 2012

Oct. 31, 2011

Oct. 31, 2013

Oct. 31, 2013

Oct. 31, 2012

Oct. 31, 2013

Oct. 31, 2013

Oct. 31, 2013

Oct. 31, 2012

Oct. 31, 2013

Oct. 31, 2013

Oct. 31, 2013

Oct. 31, 2012

Oct. 31, 2013

Oct. 31, 2013

Tax Law 2013 [Member]

Tax Law 2013 [Member]

Tax Law 2013 [Member]

Tax Law 2013 [Member]

Tax Law 2013 [Member]

Regulated Operation [Member]

Regulated Operation [Member]

Regulated Operation [Member]

Non Utility Activities [Member]

Non Utility Activities [Member]

Non Utility Activities [Member]

Internal Revenue Service IRS Member

Internal Revenue Service IRS Member

Internal Revenue Service IRS Member

Internal Revenue Service IRS Member

Internal Revenue Service IRS Member

Internal Revenue Service IRS Member

Internal Revenue Service IRS Member

Internal Revenue Service IRS Member

Internal Revenue Service IRS Member

State And Local Jurisdiction Member

State And Local Jurisdiction Member

State And Local Jurisdiction Member

State And Local Jurisdiction Member

Deferred Income Taxes [Member]

Capital Loss Carryforward

Capital Loss Carryforward

Capital Loss Carryforward

Capital Loss Carryforward

Capital Loss Carryforward

Charitable Contribution Carryforward

Charitable Contribution Carryforward

Charitable Contribution Carryforward

Charitable Contribution Carryforward

Capital Loss Carryforward

Capital Loss Carryforward

Capital Loss Carryforward

Capital Loss Carryforward

NOL Carryforward 1 [Member]

NOL Carryforward 2 [Member]

NOL Carryforward 2 [Member]

Minimum [Member]

Maximum [Member]

Minimum [Member]

Maximum [Member]

Minimum [Member]

Maximum [Member]

NOL Carryforward 2 [Member]

NOL Carryforward 2 [Member]

Operating Loss Carryforwards Abstract

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Operating Loss Carryforwards

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$178,100,000

$5,900,000

$5,900,000

'

'

$4,200,000

$2,300,000

'

'

$6,400,000

$6,800,000

'

'

Operating Loss Carryforwards Expiration Dates

'

'

'

'

'

'

'

'

'

'

'

'

'

'

31-Oct-33

'

'

31-Oct-21

31-Oct-25

'

'

31-Oct-16

31-Oct-18

'

'

31-Oct-20

31-Oct-28

Annual Amount Subject To Limitation

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'annual limitation of $0.3 million

'

'

'

'

'

'

'

'

'

'

'

Unrecognized Tax Benefits, Income Tax Penalties and Interest Expense [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Unrecognized Tax Benefits That Would Impact Effective Tax Rate

0

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Income Tax Expense Components

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Current Federal

'

'

'

'

'

'

'

'

-3,032,000

-29,062,000

-11,403,000

6,049,000

5,636,000

3,263,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Current State

'

'

'

'

'

'

'

'

919,000

1,857,000

4,209,000

984,000

1,027,000

-36,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Deferred Federal

'

'

'

'

'

'

'

'

67,885,000

86,496,000

64,806,000

2,225,000

2,214,000

4,167,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Deferred State

'

'

'

'

'

'

'

'

11,829,000

10,144,000

6,597,000

-646,000

239,000

824,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Tax Credits

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Utilization

'

'

'

'

'

'

'

'

0

0

184,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Amortization Of Investment Tax Credits

-267,000

-334,000

-325,000

'

'

'

'

'

-267,000

-334,000

-325,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total Federal

72,860,000

64,950,000

60,692,000

'

'

'

'

'

64,586,000

57,100,000

53,262,000

8,274,000

7,850,000

7,430,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Total State

13,086,000

13,267,000

11,594,000

'

'

'

'

'

12,748,000

12,001,000

10,806,000

338,000

1,266,000

788,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Income Tax Uncertainties [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Income Tax Examination, Description

'We are no longer subject to federal income tax examinations for tax years ending before and including October 31, 2009, and with few exceptions, state income tax examinations by tax authorities for years ended before and including October 31, 2009.

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Valuation Allowance Abstract

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Beginning Balance

505,000

505,000

1,324,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Charged Credited To Income Tax Expense

0

0

-819,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Ending Balance

505,000

505,000

505,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Income Tax Expense Benefit Continuing Operations Income Tax Reconciliation Abstract

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Federal Taxes At 35%

77,127,000

69,322,000

65,049,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

State Income Taxes Net Of Federal Benefit

8,506,000

8,624,000

7,536,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Amortization Of Investment Tax Credits

-267,000

-334,000

-325,000

'

'

'

'

'

-267,000

-334,000

-325,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Other, Net

580,000

605,000

26,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Income Tax Expense Total

85,946,000

78,217,000

72,286,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Deferred Tax Assets Net Abstract

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Benefit Of Loss Carryforwards

66,087,000

3,092,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Employee Benefits And Compensation

13,834,000

22,286,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Revenue Requirement

19,062,000

10,148,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Utility Plant

10,386,000

11,285,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Other

12,796,000

9,173,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total Deferred Tax Assets

122,165,000

55,984,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Deferred Tax Assets Valuation Allowance

505,000

505,000

505,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Deferred Tax Assets Net

121,660,000

55,479,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Deferred Tax Liabilities Abstract

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Utility Plant

652,822,000

523,232,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Revenues And Cost Of Gas

21,257,000

26,816,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity Method Investments

38,710,000

34,092,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Deferred Costs

59,221,000

73,744,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Other

18,324,000

8,348,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total Deferred Tax Liabilities

790,334,000

666,232,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net Deferred Income Tax Liabilities

668,674,000

610,753,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

NC Tax Law [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Statutory Tax Rate

'

'

'

'

5.00%

6.00%

6.90%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number Of Additional Rate Reductions

'

'

'

2

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Rate Reduction Percentage

'

'

'

1.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Adjustment To Noncurrent Deferred Income Tax Balances

'

'

'

25,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Operating Income Tax Expense Benefit

77,334,000

69,101,000

64,068,000

-1,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Regulatory Liabilities

$541,897,000

$489,692,000

'

'

'

'

'

$24,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity_Method_Investments_Deta

Equity Method Investments (Details) (USD $)

12 Months Ended

1 Months Ended

12 Months Ended

18 Months Ended

0 Months Ended

12 Months Ended

12 Months Ended

Oct. 31, 2013

Oct. 31, 2012

Oct. 31, 2011

Jun. 30, 2012

Oct. 31, 2013

Oct. 31, 2012

Oct. 31, 2011

Jun. 30, 2012

Jun. 22, 2012

Jul. 01, 2013

Oct. 31, 2013

Oct. 31, 2012

Oct. 31, 2011

Jun. 30, 2013

Oct. 31, 2013

Oct. 31, 2012

Oct. 31, 2011

Oct. 31, 2013

Oct. 31, 2012

Oct. 31, 2011

Oct. 31, 2013

Cardinal Pipeline Company [Member]

Cardinal Pipeline Company [Member]

Cardinal Pipeline Company [Member]

Cardinal Pipeline Company [Member]

Cardinal Pipeline Company [Member]

Cardinal Pipeline Company [Member]

Pine Needle Company [Member]

Pine Needle Company [Member]

Pine Needle Company [Member]

Pine Needle Company [Member]

Pine Needle Company [Member]

South Star Energy Services [Member]

South Star Energy Services [Member]

South Star Energy Services [Member]

Hardy Storage [Member]

Hardy Storage [Member]

Hardy Storage [Member]

Constitution Pipeline Company [Member]

Schedule Of Equity Method Investments [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Retained Earnings, Undistributed Earnings from Equity Method Investees

$0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity Method Investment Ownership Percentage

'

'

'

'

21.49%

'

'

'

'

'

45.00%

'

'

40.00%

15.00%

'

'

50.00%

'

'

24.00%

Equity Method Investment Additional Information

'

'

'

'

'

'

'

'

'

'

'In June 2013, we entered into an agreement with Hess Corporation (Hess) to acquire their 5% membership interest in Pine Needle. Effective July 1, 2013, we acquired Hess’ 5% membership interest for $2.9 million. With the purchase of this additional 5% membership interest, our membership interest in Pine Needle increased from 40% to 45%.

'

'

'

'In September 2013, GNGC contributed its retail natural gas marketing assets and customer accounts located in Illinois. AGL acquired these retail assets and customers from Nicor Inc. in December 2011 and additional retail natural gas assets and customer accounts in a separate transaction in June 2013. We made an additional $22.5 million capital contribution to SouthStar, maintaining our 15% equity ownership, related to this transaction.

'

'

'

'

'

'

Related Party Transaction Expenses From Transactions With Related Party

'

'

'

'

8,775,000

6,613,000

4,104,000

'

'

'

11,098,000

10,410,000

10,677,000

'

'

'

'

9,702,000

9,702,000

9,702,000

'

Due To Related Parties Current

'

'

'

'

755,000

855,000

'

'

'

'

940,000

914,000

'

'

'

'

'

808,000

808,000

'

'

Due From Related Parties Current

'

'

'

'

'

'

'

'

'

'

'

'

'

'

441,000

473,000

'

'

'

'

'

Summarized Financial Information Percentage

'

'

'

'

100.00%

100.00%

100.00%

'

'

'

100.00%

100.00%

100.00%

'

100.00%

100.00%

100.00%

100.00%

100.00%

100.00%

100.00%

Revenue From Related Parties

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3,291,000

2,442,000

4,961,000

'

'

'

'

Contributions to and purchase of additional interest in equity method investments

41,348,000

3,566,000

6,222,000

'

'

'

'

9,800,000

'

2,900,000

'

'

'

'

22,500,000

'

'

'

'

'

15,900,000

Distributions of capital from equity method investments

4,700,000

5,372,000

3,029,000

5,400,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cardinal Permanent Financing

'

'

'

'

'

'

'

'

45,000,000

'

'

'

'

'

'

'

'

'

'

'

'

Equity Method Investment Description Of Principal Activities

'

'

'

'

'Cardinal owns and operates an intrastate natural gas pipeline in North Carolina and is regulated by the NCUC. Cardinal has firm, long-term service agreements with local distribution companies for 100% of the firm transportation capacity on the pipeline, of which Piedmont subscribes to approximately 53%. Cardinal is dependent on the Williams – Transco pipeline system to deliver gas into its system for service to its customers.

'

'

'

'

'

'Pine Needle LNG Company, L.L.C. (Pine Needle), a North Carolina limited liability company, owns an interstate LNG storage facility in North Carolina and is regulated by the FERC. Pine Needle has firm, long-term service agreements for 100% of the storage capacity of the facility, of which Piedmont subscribes to approximately 64%.

'

'

'

'SouthStar primarily sells natural gas to residential, commercial and industrial customers in the southeastern United States, including Illinois, Ohio, New York, Maryland, North Carolina, South Carolina and Tennessee, with most of its business being conducted in the unregulated retail gas market in Georgia. We account for our investment in SouthStar using the equity method, as we have board representation with equal voting rights on significant governance matters and policy decisions, and thus, exercise significant influence over the operations of SouthStar.

'

'

'Hardy Storage owns and operates an underground interstate natural gas storage facility located in Hardy and Hampshire Counties, West Virginia, that is regulated by the FERC. Hardy Storage has firm, long-term service agreements for 100% of the storage capacity of the facility, of which Piedmont subscribes to approximately 40%.

'

'

'The purpose of the joint venture is to construct and operate approximately 120 miles of interstate natural gas pipeline and related facilities connecting shale natural gas supplies and gathering systems in Susquehanna County, Pennsylvania, to the Iroquois Gas Transmission and Tennessee Gas Pipeline systems in New York. We have committed to fund an amount in proportion to our ownership interest for the development and construction of the new pipeline, which is expected to cost approximately $680 million. we expect our total contributions will be an estimated $55 million and $92.1 million in our fiscal 2014 and 2015 years, respectively. The target in-service date of the project is March 2015. The capacity of the pipeline is 100% subscribed under fifteen year service agreements with two Marcellus producer-shippers with a negotiated rate structure.

Equity Method Investment Summarized Financial Information [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Current Assets

'

'

'

'

15,179,000

9,179,000

'

'

'

'

9,225,000

11,937,000

'

'

194,793,000

152,422,000

'

7,641,000

10,302,000

'

10,944,000

Non Current Assets

'

'

'

'

116,414,000

120,437,000

'

'

'

'

74,710,000

77,463,000

'

'

136,753,000

9,803,000

'

161,282,000

164,374,000

'

62,438,000

Current Liabilities

'

'

'

'

2,637,000

1,786,000

'

'

'

'

3,531,000

4,278,000

'

'

76,304,000

42,197,000

'

12,378,000

14,534,000

'

7,960,000

Non Current Liabilities

'

'

'

'

45,273,000

45,702,000

'

'

'

'

35,391,000

35,851,000

'

'

53,000

1,000

'

87,184,000

95,061,000

'

0

Revenues

'

'

'

'

17,649,000

16,165,000

13,633,000

'

'

'

16,810,000

16,390,000

17,666,000

'

639,426,000

585,291,000

733,987,000

24,375,000

24,359,000

24,378,000

0

Gross Profit (Loss)

'

'

'

'

17,649,000

16,165,000

13,633,000

'

'

'

16,810,000

16,390,000

17,666,000

'

174,993,000

161,122,000

176,010,000

24,375,000

24,359,000

24,378,000

0

Income Before Income Taxes

'

'

'

'

9,361,000

10,433,000

6,473,000

'

'

'

5,804,000

5,832,000

5,763,000

'

103,146,000

94,631,000

103,704,000

10,582,000

9,939,000

9,657,000

3,459,000

Pipeline Subscription Capacity Percentage

'

'

'

'

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

Pipeline Transportation Capacity Subscribed

'

'

'

'

53.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Storage Capacity Subscription Percentage

'

'

'

'

'

'

'

'

'

'

100.00%

'

'

'

'

'

'

100.00%

'

'

'

Storage Capacity Subscribed

'

'

'

'

'

'

'

'

'

'

64.00%

'

'

'

'

'

'

40.00%

'

'

'

Additional Equity Method Ownership Percentage Acquired

'

'

'

'

'

'

'

'

'

5.00%

'

'

'

'

'

'

'

'

'

'

'

Estimated Piedmont Contributions To Pipeline Project Next Fiscal Year

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

55,000,000

Estimated Piedmont Contributions To Pipeline Project In Two Fiscal Years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

92,100,000

Term Pipeline Subscription Agreements

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'15 years

Estimated Pipeline Development And Construction Costs

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$680,000,000

Pipeline Target In Service Date

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'March 2015

Variable_Interest_Entities_Det

Variable Interest Entities (Details) (USD $)	Oct. 31, 2013	Oct. 31, 2012
Variable Interest Entity [Line Items]	'	'
Variable Interest Entity, Nonconsolidated, Carrying Amount, Assets	$128,469,000	$87,867,000
Cardinal Pipeline Company [Member]	'	'
Variable Interest Entity [Line Items]	'	'
Variable Interest Entity, Nonconsolidated, Carrying Amount, Assets	18,207,000	17,969,000
Pine Needle Company [Member]	'	'
Variable Interest Entity [Line Items]	'	'
Variable Interest Entity, Nonconsolidated, Carrying Amount, Assets	20,270,000	19,239,000
South Star Energy Services [Member]	'	'
Variable Interest Entity [Line Items]	'	'
Variable Interest Entity, Nonconsolidated, Carrying Amount, Assets	38,372,000	18,118,000
Hardy Storage [Member]	'	'
Variable Interest Entity [Line Items]	'	'
Variable Interest Entity, Nonconsolidated, Carrying Amount, Assets	34,681,000	32,541,000
Constitution Pipeline Company [Member]	'	'
Variable Interest Entity [Line Items]	'	'
Variable Interest Entity, Nonconsolidated, Carrying Amount, Assets	$16,939,000	$0

Business_Segments_Details

Business Segments (Details) (USD $)	3 Months Ended								12 Months Ended
	Oct. 31, 2013	Jul. 31, 2013	Apr. 30, 2013	Jan. 31, 2013	Oct. 31, 2012	Jul. 31, 2012	Apr. 30, 2012	Jan. 31, 2012	Oct. 31, 2013	Oct. 31, 2012	Oct. 31, 2011
Segment Reporting Information [Abstract]	'	'	'	'	'	'	'	'	'	'	'
Revenues from external customers	$200,000,000	$162,943,000	$399,411,000	$515,875,000	$181,385,000	$161,123,000	$308,432,000	$471,840,000	$1,278,229,000	$1,122,780,000	$1,433,905,000
Margin	109,011,000	97,000,000	183,856,000	231,623,000	96,798,000	86,460,000	171,951,000	220,237,000	621,490,000	575,446,000	573,639,000
Operations and maintenance expenses	'	'	'	'	'	'	'	'	253,301,000	242,701,000	225,460,000
Depreciation	'	'	'	'	'	'	'	'	112,225,000	103,210,000	102,857,000
Income from equity method investments	'	'	'	'	'	'	'	'	26,056,000	23,904,000	24,027,000
Interest expense	'	'	'	'	'	'	'	'	24,938,000	20,097,000	43,992,000
Operating Income (Loss) Before Income Taxes	'	'	'	'	'	'	'	'	221,176,000	194,560,000	206,959,000
Income before income taxes	'	'	'	'	'	'	'	'	220,363,000	198,064,000	185,854,000
Total assets	4,182,423,000	'	'	'	3,563,887,000	'	'	'	4,182,423,000	3,563,887,000	3,054,093,000
Equity method investments in non-utility activities	128,469,000	'	'	'	87,867,000	'	'	'	128,469,000	87,867,000	85,121,000
Utility capital expenditures	'	'	'	'	'	'	'	'	599,999,000	529,576,000	243,641,000
Segment Reporting Information Operating Income Loss Abstract	'	'	'	'	'	'	'	'	'	'	'
Segment Operating Income Before Income Taxes	'	'	'	'	'	'	'	'	221,176,000	194,560,000	206,959,000
Utility income taxes	'	'	'	'	'	'	'	'	77,334,000	69,101,000	64,068,000
Non Utility Activities Before Income Taxes	'	'	'	'	'	'	'	'	352,000	264,000	120,000
Operating Income	5,886,000	591,000	51,504,000	86,213,000	-365,000	-2,513,000	48,782,000	79,819,000	144,194,000	125,723,000	143,011,000
Net Income by segment	'	'	'	'	'	'	'	'	'	'	'
Income before income taxes for reportable segments	'	'	'	'	'	'	'	'	220,363,000	198,064,000	185,854,000
Income taxes	'	'	'	'	'	'	'	'	-85,946,000	-78,217,000	-72,286,000
Net Income	-5,003,000	-2,293,000	55,790,000	85,923,000	-1,959,000	-4,613,000	50,192,000	76,227,000	134,417,000	119,847,000	113,568,000
Segment Consolidated Assets [Abstract]	'	'	'	'	'	'	'	'	'	'	'
Total Assets	4,368,609,000	'	'	'	3,769,939,000	'	'	'	4,368,609,000	3,769,939,000	'
Segment Reporting, Disclosure of Major Customers	'	'	'	'	'	'	'	'	'No single customer accounts for more than 10% of our consolidated revenues.	'	'
Number Of Operating Segments	'	'	'	'	'	'	'	'	2	'	'
Operating Segments [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment Consolidated Assets [Abstract]	'	'	'	'	'	'	'	'	'	'	'
Total Assets	4,182,423,000	'	'	'	3,563,887,000	'	'	'	4,182,423,000	3,563,887,000	'
Corporate Elimination [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment Consolidated Assets [Abstract]	'	'	'	'	'	'	'	'	'	'	'
Total Assets	186,186,000	'	'	'	206,052,000	'	'	'	186,186,000	206,052,000	'
Regulated Operation [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Abstract]	'	'	'	'	'	'	'	'	'	'	'
Revenues from external customers	'	'	'	'	'	'	'	'	1,278,229,000	1,122,780,000	1,433,905,000
Margin	'	'	'	'	'	'	'	'	621,490,000	575,446,000	573,639,000
Operations and maintenance expenses	'	'	'	'	'	'	'	'	253,120,000	242,599,000	225,351,000
Depreciation	'	'	'	'	'	'	'	'	112,207,000	103,192,000	102,829,000
Income from equity method investments	'	'	'	'	'	'	'	'	0	0	0
Interest expense	'	'	'	'	'	'	'	'	24,938,000	20,097,000	43,992,000
Operating Income (Loss) Before Income Taxes	'	'	'	'	'	'	'	'	221,528,000	194,824,000	207,079,000
Income before income taxes	'	'	'	'	'	'	'	'	194,659,000	174,424,000	161,925,000
Total assets	4,053,591,000	'	'	'	3,475,640,000	'	'	'	4,053,591,000	3,475,640,000	2,968,574,000
Equity method investments in non-utility activities	0	'	'	'	0	'	'	'	0	0	0
Utility capital expenditures	'	'	'	'	'	'	'	'	599,999,000	529,576,000	243,641,000
Segment Reporting Information Operating Income Loss Abstract	'	'	'	'	'	'	'	'	'	'	'
Segment Operating Income Before Income Taxes	'	'	'	'	'	'	'	'	221,528,000	194,824,000	207,079,000
Non Utility Activities [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Abstract]	'	'	'	'	'	'	'	'	'	'	'
Revenues from external customers	'	'	'	'	'	'	'	'	0	0	0
Margin	'	'	'	'	'	'	'	'	0	0	0
Operations and maintenance expenses	'	'	'	'	'	'	'	'	181,000	102,000	109,000
Depreciation	'	'	'	'	'	'	'	'	18,000	18,000	28,000
Income from equity method investments	'	'	'	'	'	'	'	'	26,056,000	23,904,000	24,027,000
Interest expense	'	'	'	'	'	'	'	'	0	0	0
Operating Income (Loss) Before Income Taxes	'	'	'	'	'	'	'	'	-352,000	-264,000	-120,000
Income before income taxes	'	'	'	'	'	'	'	'	25,704,000	23,640,000	23,929,000
Total assets	128,832,000	'	'	'	88,247,000	'	'	'	128,832,000	88,247,000	85,519,000
Equity method investments in non-utility activities	128,469,000	'	'	'	87,867,000	'	'	'	128,469,000	87,867,000	85,121,000
Utility capital expenditures	'	'	'	'	'	'	'	'	0	0	0
Segment Reporting Information Operating Income Loss Abstract	'	'	'	'	'	'	'	'	'	'	'
Segment Operating Income Before Income Taxes	'	'	'	'	'	'	'	'	($352,000)	($264,000)	($120,000)

Subsequent_Events_Details

Subsequent Events (Details) (USD $)	0 Months Ended	12 Months Ended					0 Months Ended	12 Months Ended
	Feb. 04, 2013	Oct. 31, 2013	Oct. 31, 2012	Oct. 31, 2011	Oct. 31, 2013	Oct. 31, 2013	Dec. 16, 2013	Oct. 31, 2013	Nov. 02, 2013	Nov. 30, 2013
					Revolving Credit Facility [Member]	Commercial Paper [Member]	Subsequent Event	Subsequent Event	Subsequent Event	Subsequent Event
									Revolving Credit Facility [Member]	Commercial Paper [Member]
Subsequent Event [Line Items]	'	'	'	'	'	'	'	'	'	'
Forward Settlement Date	'	'	'	'	'	'	'	16-Dec-13	'	'
Common Stock Issued, Shares	3,000,000	3,000,000	'	'	'	'	1,600,000	'	'	'
Common Stock Issued, Value	$92,600,000	$119,552,000	$22,198,000	$24,155,000	'	'	$47,300,000	'	'	'
Net Settlement Price Per Share	$30.88	'	'	'	'	'	$30.88	'	'	'
Credit Facility Current Borrowing Capacity	'	'	'	'	$650,000,000	$650,000,000	'	'	$850,000,000	$850,000,000

Selected_Quarterly_Financial_D2

Selected Quarterly Financial Data (Details) (USD $)	3 Months Ended								12 Months Ended
	Oct. 31, 2013	Jul. 31, 2013	Apr. 30, 2013	Jan. 31, 2013	Oct. 31, 2012	Jul. 31, 2012	Apr. 30, 2012	Jan. 31, 2012	Oct. 31, 2013	Oct. 31, 2012	Oct. 31, 2011
Quarterly Financial Data [Abstract]	'	'	'	'	'	'	'	'	'	'	'
Operating Revenues	$200,000,000	$162,943,000	$399,411,000	$515,875,000	$181,385,000	$161,123,000	$308,432,000	$471,840,000	$1,278,229,000	$1,122,780,000	$1,433,905,000
Margin	109,011,000	97,000,000	183,856,000	231,623,000	96,798,000	86,460,000	171,951,000	220,237,000	621,490,000	575,446,000	573,639,000
Operating Income (Loss)	5,886,000	591,000	51,504,000	86,213,000	-365,000	-2,513,000	48,782,000	79,819,000	144,194,000	125,723,000	143,011,000
Net Income (Loss)	($5,003,000)	($2,293,000)	$55,790,000	$85,923,000	($1,959,000)	($4,613,000)	$50,192,000	$76,227,000	$134,417,000	$119,847,000	$113,568,000
Earnings Per Share of Common Stock	'	'	'	'	'	'	'	'	'	'	'
Basic	($0.07)	($0.03)	$0.74	$1.19	($0.03)	($0.06)	$0.70	$1.06	$1.80	$1.67	$1.58
Diluted	($0.07)	($0.03)	$0.74	$1.18	($0.03)	($0.06)	$0.70	$1.05	$1.78	$1.66	$1.57